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209-121
DATA SUBMITTAL COMPLIANCE REPORT 2/16/2011 Permit to Drill 2091210 Well Name /No. KUPARUK RIV UNIT 31 -11L1 Operator CONOCOPHILLIPS ALASKA INC API No. 50- 029 - 21932 -60 -00 MD 9437 TVD 6214 Completion Date Completion Status SUSP Current Status P &A UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Surve - DATA INFORMATION • Types Electric or Other Logs Run: GR / CCL / PRESS / TEMP (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH 1 Type MedlFrmt Number Name Scale Media No Start Stop CH Received Comments ED C Lis 19561 Induction /Resistivity Open 4/23/2010 TIFF, GMD and PDF of EWR logs Log Induction /Resistivity 2 Col 6409 9437 Open 4/23/2010 MD MPR, GR Log Induction /Resistivity 5 Col 6409 9437 Open 4/23/2010 MD MPR, GR Log Induction /Resistivity /S Col 6409 9437 Open 4/23/2010 TVD MPR, GR ED C Asc Directional Survey 6400 9437 Open Rpt _ Directional Survey 6400 9437 Open Well Cores /Samples Information: Sample Interval Set III Name Start Stop Sent Received Number Comments 1 ADDITIONAL INFORMAO N Well Cored? Y / N Daily History Received? r N Chips Received? - Y - f -N—' Formation Tops U/ N Analysis 4-L111.- Received? Comments: DATA SUBMITTAL COMPLIANCE REPORT 2/16/2011 Permit to Drill 2091210 Well Name /No. KUPARUK RIV UNIT 31 -11L1 Operator CONOCOPHILLIPS ALASKA INC API No. 50 -029- 21932 -60 -00 MD 9437 TVD 6214 Completion Date Completion Status SUSP Current Status P&A UIC N Compliance Reviewed By: Date:6 Fel _._ • l • • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended in l b. Well Class: 20AAC 25.105 20AAC 25.110 Development Eg Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No. of Completions: Service ❑ Stratigraphic Test 2. Operator Name: 5. Date Comp., Susp., 12. Permit to Drill Number: ConocoPhillips Alaska, Inc. or Aband.: July 23, 2010 209 - 121 / 310 - 177 3. Address: 6. Date Spudded: 13. API Number: P. O. Box 100360, Anchorage, AK 99510 - 0360 January 30, 2010 50 029 - 21932 - 60 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 147' FSL, 48' FEL, Sec. 36, T13N, R8E, UM February 6, 2010 3I Top of Productive Horizon: 8. KB (ft above MSL): 76' RKB 15. Field /Pool(s): 705' FNL, 1022' FEL, Sec. 6, T12N, R9E, UM GL (ft above MSL): ' AMSL Kuparuk River Field Total Depth: 9. Plug Back Depth (MD + TVD): 2680' FNL, 2444' FEL, Sec. 6, T12N, R9E, UM 6406' MD / 6217' TVD Kuparuk River Oil Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x 507830 y 6007088 Zone 4 9437' MD / 6214' TVD ADL 25523, 25631 TPI: x - 507383 y - 6006236 Zone 4 11. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x 505970 y- 6004260 Zone 4 NONE 2437 18. Directional Survey: Yes In No ❑ 19. Water Depth, if Offshore: 20. Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1650' MD / 1650' TVD 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re drill /Lateral Top Window MD/TVD GR /CCUPress/Temp 6408' MD / 6218' TVD 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 16" 62.5# H - 40 Surf. 116' Surf. 116' 24" 250 sx CS II 9.625" 36# J -55 Surf. 3383' Surf. 3383' 12.25" 330 sx CI G, 544 sx AS III, 175 sx AS I 7" 26# J - Surf. 6408' Surf. 6141' 8.5" 250 sx Class G, 175 sx AS I 2.375" 4.6# L -80 7591' 9437' 6226' 6214' 3" liner 24. Open to production or injection? Yes ❑ No in If Yes, list each 25. TUBING RECORD Interval open (MD +TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET ( MD/TVD) � � � RECE tbg in main wellbore 6146' MD / 5977' TVD � None- plugged off. y fl r1 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. t I J ( 2 p 1 0 DEPTH INTERVAL D) AMOUNT AND KIND OF MATERIAL USED CIBP 6406' A1as'r a g z PR; Cam, C mssion 27 . PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) suspended Date of Test Hours Tested Production for OIL -BBL GAS -MCF WATER -BBL CHOKE SIZE GAS - OIL RATIO Test Period - -> Flow Tubing Casing Pressure Calculated OIL -BBL GAS -MCF WATER -BBL OIL GRAVITY - API (corr) Press. psi 24 -Hour Rate -> 28. CORE DATA Conventional Core(s) Acquired? Yes ❑ No J Sidewall Cores Acquired? Yes ❑ No 0 If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. 4 " NONE 4 ` n� Form 10 -407 Revised 12/2009 CONTINUED ON REVERSE Submit original only RBDMS AUG 8- 2010 , c'1-2-2-- (0 _tee y, /,a c 28. GEOLOGIC MARKERS (List all formations and markers encountered): 29. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes A No If yes, list intervals and formations tested, Permafrost - Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form, if Permafrost - Bottom 1650' 1650' needed, and submit detailed test information per 20 AAC 25.071. Top Kuparuk A 6429' 6237' Bottom Kuparuk A 9437' 6214' Top Kuparuk B 6418' 6227' Bottom Kuparuk B 6418' 6227' 0 N/A Formation at total depth: Kuparuk A2 30. LIST OF ATTACHMENTS Summary of Daily Operations, schematic, directional survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jill ��Long 263 - 4093 �p7 pp 4iI, Printed Nam- / V Cawve Title: Alaska Wells Manager / Signature i .L o , 1 (1tL 4Jey Phone 265 -6306 Date Oil 3110 Sharon Allsup -Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10 -407 well completion report and 10 -404 well sundry report when the downhole well design is changed. Item la: Classification of Service wells: Gas injection, water injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50- 029 - 20123- 00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -in, or Other (explain). * • Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10 -407 Revised 12/2009 • 31 -11 Well Events Summary DATE SUMMARY • 3/9/10 DRIFT W/ 2.85" BRUSH, TAGGED TOP OF WHIPSTOCK @ 6404' SLM. COMPLETE. 4/4/10 TAGGED FILL / BRIDGE @ 6062' SLM. ATTEMPTED BAILING WITHOUT SUCCESS. RECOVERED MINIMAL SAND. READY FOR CTU. 4/20/10 MOBILIZED CTU #3 FROM DEADHORSE. PERFORMED REQUIRED BOPE FUNCTION /PRESSURE TESTING. 4/21/10 PERFORMED FILL CLEAN -OUT FROM INITIAL TAG AT 6077.0', DOWN TO 6246.0' CTMD PUMPING 1.9- BPM SLICK - DIESEL AND DIESEL GEL. MAINTAINED 1:1 RETURNS THROUGHOUT JOB. EXPERIENCED EASILY - LIFTED FILL IN ADDITION TO SEVERAL HARD AREAS WITH VERY LOW PENETRATION RATES. ORDERED MORE FLUIDS TO CONTINUE IN A.M. 4/22/10 PERFORMED FILL CLEAN -OUT TO 6420.5' CTMD PUMPING 2.0 -BPM SLICK - DIESEL AND DIESEL GEL. MAINTAINED 1:1 RETURNS THROUGHOUT JOB. LIGHT FORMATION SANDS AND PEA -SIZED ANGULAR GRAVEL IN RETURNS; MODERATE CONCENTRATIONS IN GEL PILLS (SAMPLE OBTAINED). LEFT WELL SHUT -IN AND FREEZE PROTECTED. 4/26/10 TAGGED WHIPSTOCK @ 6410' SLM. COMPLETE. 6/11/10 LOG GR /CCUPRESS/TEMP FOR PRE SIDETRACK REFERENCE LOG. LOGGED BHPS: 6400'= 3962 PSI, 156 DEGF & 6300'= 3927 PSI, 152 DEGF. 6/14/10 DRIFT TBG W/ 2.78" DMY PLUG (OAL = 46 ") TO 6170' RKB. PULLED GLV © 5668' RKB, LOST TOOL STRING @ —5200' SLM. TAG FISH W/ 2.74" LIB @ 5607' SLM (CLEAN ROPE SOCKET W/ WIRE PRESENT) FISH IN GLM @ 5668' RKB. FISH IN HOLE= 37.5' OAL & —30' OF .108 WIRE. IN PROGRESS. 6/15/10 ATTEMPTED PULL 37.5' TOOLSTRING FROM 5607' SLM. PUMPED 11 BBL DSL, T & IA TRACKED TO 2500 PSI; APPARENT SAND BRIDGE IN TBG. MOVED FISH UPHOLE 28' TO 5579' SLM. IN PROGRESS. 6/16/10 RECOVERED —30' WIRE & TOOLSTRING LOST 6/14/2010. 1.5" GLV PULLED 6/14/2010 MISSING IN WELL. IN PROGRESS. 6/17/10 RECOVERED GLV LOST 6/14/10. BAILED THROUGH SAND BRIDGES @ 6095' & 6122' SLM. TAGGED WITH 2.79" GAUGE @ 6391' SLM. BRUSHED X NIPPLE @ 6123' RKB & SET 2.813" XX PLUG @ SAME. IN PROGRESS. 6/18/10 SET CATCHER ON XX PLUG @ 6123' RKB. PULLED GLVs © 4760', 3702' & 2511' RKB. SET DVs @ 5667', 4760', 3702' & 2511' RKB. BLED IA TO VERIFY VALVES ARE SET; TBG TRACKING IA. PULLED OV @ 6074' RKB, CHECK OK. IN PROGRESS. 6/19/10 VERIFIED DVs SET WITH HOLEFINDER. CIRCULATED 50 BBL DSL TO LOAD WELL. SET DV @ 6074' RKB. TESTED TBG 2000 PSI, PASSED. DRAW DOWN TEST ON IA, PASSED. MITIA 2500 PSI, PASSED. PULLED CATCHER SUB. IN PROGRESS. 6/20/10 PULLED 2.81" XX PLUG C, 6123' RKB. DRIFTED & TAGGED @ 6395' SLM, EST. 6418' RKB, WITH 2.63" CENT, BLB & 2.77" LIB (OAL =55 "). LIB INDICATES FILL. CL RE TESTED TRMAXX -5E SSSV, GOOD. READY FOR E/L. 6/22/10 SET BAKER 3.5" CIBP. TOP OF CIBP SET AT A DEPTH OF 405.85'. BOTTOM OF CIBP SET AT A DEPTH OF 6407'. CCL TO BOTTOM OF CIBP MEASURED 14.96'. CCL STOP DEPTH RECORDED AT 6392'. 6/28/10 PERFORM POS/ NEG TESTS ON CIBP. DRIFTED TBG WITH DUMMY WHIPSTOCK (2.65" x 18.3') TO TOP OF CIBP @ 6406' RKB. COMPLETE. 7/7/10 T -POT (PASSED), T -PPPOT (PASSED), IC -POT (PASSED), IC -PPPOT (PASSED), MITOA (PASSED), PT & DD TEST ON SV (PASSED), MV (PASSED), SSV (PASSED) Conoco Phillips Time Log & Summary Webview Web RepoRing Report Well Name: 31 - 11 Rig Name: NABORS CDR2 - AC Job Type: DRILLING SIDETRACK Rig Accept: 7/20/2010 7:00:00 AM Rig Release: 8/6/2010 4:00:00 PM Time Logs . Date. From To =Dur S. Depth E. Depth Phase Code Subcode T Comment n._ 07/19/2010 24 hr s ummary Rig Released from 1 R -06, travel to 31 -11 10:00 21:30 11.50 MIRU MOVE MOB T Move from 1R-06 to 31 -11 21:30 00:00 2.50 MIRU MOVE MOB T Arrive at 31, remove jeeps from units, site inspection with DSO. Spot Sub module over well. 07/20/2010 Test GOP's, remove BPV, start cutting CT 00:00 07:00 7.00 MIRU MOVE MOB T MIRU, 07:00 08:00 1.00 MIRU WHDBO NUND T Rig Accepted. Nipple up second swab and wing valves 08:00 10:30 2.50 MIRU WHDBO NUND T Nipple up BOP stack 10:30 20:30 10.00 MIRU WHDBO BOPE P BOP testing 20:30 00:00 3.50 SURPRI WELLPF SLPC P LD test joint, RU remove BPV. Prepare to cut CT 07/21/2010 Com lete BOP testing, cut 3300' CT, PU/MU and RIH WS setting at 6394.6' TOWS. POOH. PU /MU milling BHA, RIH at 4650' CTMD Injector making loud scraping noises. POOH to repair 00:00 03:00 3.00 SURPRI WELLPF SLPC P Cutting CT 03:00 03:45 0.75 SURPRI WELLPFSFTY P Stop operations due to floor hand getting struck in cheek with E -line. Send worker to medic. Hold PJSM on incident. Discuss operation procedure and what to do different in order for cable not to strike anyone. Cut E -line with every CT cut 03:45 07:00 3.25 SURPRI WELLPF SLPC P Continue cutting CT 07:00 08:00 1.00 SURPRI WELLPF SLPC P RU to pump slack, replaced all o -rings on lubricator, pump slack 08:00 08:30 0.50 SURPRI WELLPF SLPC P Cut addtional 38' to find wire. Cut total of 3290' CT 08:30 11:00 2.50 SURPRI WELLPF SLPC P Install CTC and pull test to 40K. MU e -line head and PT to 4000 PSI. PT both PDLs to 4000 PSI. PT tiger tank line to 4000 PSI 11:00 12:00 1.00 SURPRI WELLPF SLPC P Stab injector to well and pump forward 1.5 CT volume at 1.5 BPM 12:00 13:00 1.00 PROD1 RPEQPI PULD T MU whipstock BHA 13:00 15:00 2.00 PROD1 RPEQP1TRIP T RIH, Tie in at 6240, +11'. 28K PUW, 20K RIW. Tag CIBP at 6404.7 with 2.4K WOB. PU and tag at 6404.5 with 800 WOB. Set WS with .5 BPM, 3000 PSI. TOWS at 6394.6 Page 1 of 15 • • TimesLogs Date = From To Dur S. Depth E. Depth Phase Code ' Subcode T Comment.., -. 15:00 15:30 0.50 PROD1 RPEQPI CIRC T Circulate well over to 9.4 flo -pro for milling operations. 15:30 17:00 1.50 PROD1 RPEQP1TRIP T POOH 17:00 18:00 1.00 PROD1 RPEQP1PULD T Lay down 18:00 18:30 0.50 PROD1 RPEQPISFTY P Crew Change, PJSM 18:30 19:30 1.00 0 0 PROD1 WHPST PULD T PU /MU Milling BHA, Service injector head. 19:30 20:30 1.00 71 4,675 PROD1 WHPST TRIP T RIH 20:30 21:00 0.50 4,675 4,675 PROD1 WHPST TRIP T Loud abnormal noises coming from injector head, Skate bearings broke in skates. "****NABORS down time *"' 1/2 hour billable repair time, 2 1/2 hours non billable. 21:00 00:00 3.00 4,675 0 PROD1 WHPST TRIP T POOH 07/22/2010 Complete repairs on injector, PU milling BHA mill window 00:00 01:00 1.00 1,650 595 PROD1 WHPST TRIP T Stop POOH, Injector making loud crunching noises. Inspect. Bearings crunching. 01:00 02:00 1.00 595 0 PROD1 WHPST TRIP T Continue POOH 5 -10 FPM, with extreme caution, monitoring for pipe damage. 02:00 02:15 0.25 0 0 PROD1 WHPST SFTY T At surface, hold PJSM 02:15 02:45 0.50 0 0 PROD1 WHPST PULD T LD BHA 02:45 03:00 0.25 0 0 PROD1 RIGMN7 RGRP T PJSM, Prepare to unstab CT 03:00 04:00 1.00 0 0 PROD1 RIGMN7 RGRP T Prepare to unstab CT 04:00 04:30 0.50 0 0 PROD1 RIGMN7 RGRP T Unstab CT 04:30 15:00 10.50 0 0 PROD1 RIGMN7 RGRP T Repair skates from injector head 15:00 17:00 2.00 0 0 PROD1 RIGMN7 RGRP T Install CTC, pull test to 40K, install e -line head /UQC, PT to 4000 psi. 17:00 18:15 1.25 0 0 PROD1 RIGMNT RGRP T PJSM, MU milling BHA 18:15 19:00 0.75 73 4,675 PROD1 WHPST TRIP T RIH 19:00 19:42 0.70 4,675 6,259 PROD1 WHPST TRIP T Continue RIH * ** *Nabors back on billable time'"**" Total of 19 hours of non - billable repair time for the day 19:42 19:48 0.10 6,259 6,286 PROD1 WHPST DLOG T Tie in depth, correct +6' Perform weight check 15.5K, RIH 19:48 20:00 0.20 6,286 6,394 PROD1 WHPST MILL T Dry tag pinch point 6394.4', PU online with pumps 1.4BPM, 2378 CTP, 361 off bottom Diff PSI, RIH Page 2 of 15 • • TimeLogs Date From = To _ ,." Dui S. 'Depth:- E Depth Phase ' Code - Subcode T Comment ' . 20:00 00:00 4.00 6,394 6,397 PROD1 WHPST MILL T Start milling 6394.2, .5 -2.5K WOB, 80 -175 diff psi, 1 FPH keeping diff psi lower than 300 psi. 07/23/2010 Milled TOW from 6394.2' to 6403'. Mill additional 7' of formation to 6410.2'. Back ream & dry run were clean. Swap mud, POOH. 00:00 00:30 0.50 6,397 6,398 PROD1 WHPST MILL T Indication mill is in center line of 3.5 ", WOB increasing, motor work decreasing, Continue to mill .5 -1 FPH, 80 -175 diff psi, 2 -3K WOB with WOB dropping off and diff psi increasing. slowing ROP at times to let mill off 00:30 02:45 2.25 6,398 6,400 PROD1 WHPST MILL T Indication mill has made contact with 7 ", WOB and motorwork increasing together, stop milling. Back ream up and down 3 times, Looks good. Offline with pumps, dry run up and down, Looks good. 02:45 04:42 1.95 6,400 0 PROD1 WHPST TRIP T POOH 04:42 07:00 2.30 0 74 PROD1 WHPST PULD T Flow check well and swap BHA, with crew change out 07:00 08:48 1.80 73 6,240 PROD1 WHPST TRIP T RIH. Taking thermal images at variable speeds and traction pressure settings 08:48 09:06 0.30 6,240 6,399 PROD1 WHPST DLOG T Tie in, 09:06 14:06 5.00 6,399 6,403 PROD1 WHPST MILL T Start time milling, 2500 CTP, 530 (itt PSI DH differential pressure at free spin, 12K RIW, 22K PUW 14:06 14:51 0.75 6,403 6,404 PROD1 WHPST MILL T Lose WOB, Indication milling bottom of window, Continue milling 1 FPH 14:51 18:51 4.00 6,404 6,409 PROD1 WHPST MILL T 15% formation in returns confirming casing exit, start closing MP choke to 300psi. Add 50psi every 1 foot drilled. Continue drilling formation 1 FPH. 18:51 20:51 2.00 6,409 6,410 PROD1 WHPST MILL T Increased to 2 fph while drilling r � formation down to 6410.2' 'v 20:51 22:30 1.65 6,410 6,410 PROD1 WHPST REAM T Backreaming passes - 1st pass HS l slight weight drag @ 6399', second pass - clean. 45 ROHS - slight motor work - clean 3N1A- weight 45 LOHS - slight motor work - weight drag @ 6405' - due to roliing TF all the way around. 45 LOHS - slight motor work - clean weight 22:30 23:00 0.50 6,410 6,300 PROD1 WHPST CIRC T Dry run- clean. P/U to 6350' and perform mud swap. 23:00 00:00 1.00 6,300 2,000 PROD1 WHPST TRIP T POOH to change BHA 07/24/2010 Drill build to 6635', log RA tag @ 6401'. TOW = 6394.6', BOW = 6403.6'. Pull BHA # 6 due to motor failure. Window drifts are clean. _ 00:00 01:00 1.00 2,000 74 PROD1 WHPST TRIP T POOH. CT © surface, hold pre -job for undeploying. Page 3 of 15 Nov ConocoPhillips Alaska ConocoPhillips(Alaska) Inc. • Kuparuk River Unit Kuparuk 31 Pad 31 -11L1 500292193260 Baker Hughes INTEQ Mal BAKER Definitive Survey Report HUGHES 17 February, 2010 r' i ConocoPhillips • ConfacoP idhi S r rUR Definitive Survey Report Ht Alaska Company: ConocoPhillips(Alaska) Inc. Local Co- ordinate Reference: 31 - 11 Project: Kuparuk River Unit TVD Reference: 31 -11 @ 76.00ft (31 -11) Site: Kuparuk 31 Pad MD Reference: 31 -11 @ 76.00ft (31 -11) Well: 31 - 11 North Reference: TRUE Welibore: 31 - 11 Survey Calculation Method: Minimum Curvature Design: 31 -11 Database; EDM Alaska Prod v16 Project Kuparuk River Unit Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well 31-11 Well Position +N / -S 0.00 ft Northing: 6,007,088.16ft Latitude: 70° 25' 50.121 N +E / -W 0.00 ft Easting: 507,830.23ft Longitude: 149° 56' 10.241 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 0.00 ft I Wellbore 31-11L1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength ( °) ( °) (nT) BGGM2009 1/7/2010 17.24 79.84 57,364 Design 3I Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 6,400.00 Vertical Section; Depth From (TVD) +N / -S +E/ W Direction 76.00 0.00 0.00 213.39 Survey Program Date From To Survey Survey (ft) (ft) Survey (Welibore) Toot Name Description Start Date End Date 100.00 6,400.00 31 -11 (31 -11) BOSS -GYRO Sperry-Sun BOSS gyro multishot 1/12/2001 6,409.00 9,397.55 31-11L1 (31-11L1) MWD MWD - Standard 2/1/2010 2/6/2010 2/17/2010 10:29 :28AM Page 2 COMPASS 2003.16 Build 69 r•" ConocoPhillips s* CortocoPhillips Definitive Survey Report NESS Alaska Company: ConocoPhillips(Alaska) Inc. Local Coordinate Reference: 31 - 11 Project: Kuparuk River Unit TVD Reference: 31 -11 @ 76.00ft (31 -11) Site: Kuparuk 31 Pad MD Reference: 31 -11 @ 76.00ft (31 -11) Well: 31 - 11 North Reference: TRUE Wellbore: 31 - 11 Survey Calculation Method: Minimum Curvature Design: 31 - 11 Database: EDM Alaska Prod v16 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N / -S +E / -W Northing Easting DLS Section (ft) ( °) ( °) (ft) (ft) (ft) (ft) (ft (ft) 0100') (ft) Survey Toot Name Annotation 6,400.00 21.98 210.19 6,210.60 6,134.60 - 845.69 - 445.06 6,006,242.09 507,386.10 2.06 951.04 MWD (2) TIP 31 - • 6,409.00 21.90 210.21 6,218.95 6,142.95 - 848.60 - 446.75 6,006,239.18 507,384.41 0.89 954.40 MWD (2) KOP 6,439.39 38.43 202.56 6,245.14 6,169.14 - 862.32 - 453.28 6,006,225.45 507,377.90 55.74 969.44 MWD (2) Interpolated Azi 6,469.40 46.03 198.50 6,267.35 6,191.35 - 881.20 - 460.29 6,006,206.56 507,370.91 26.90 989.07 MWD (2) Interpolated Azi 6,499.27 54.99 195.83 6,286.33 6,210.33 - 903.21 - 467.06 6,006,184.55 507,364.17 30.77 1,011.17 MWD (2) 6,529.13 63.78 199.60 6,301.53 6,225.53 - 927.65 - 474.90 6,006,160.11 507,356.35 31.37 1,035.89 MWD (2) 6,559.46 72,61 203.11 6,312.78 6,236.78 - 953.83 - 485.17 6,006,133.91 507,346.11 31.03 1,063.41 MWD (2) 6,589.29 82.12 203.49 6,319.30 6,243.30 - 980.54 - 496.67 6,006,107.20 507,334.64 31.90 1,092.03 MWD (2) 6,619.30 92.64 202.33 6,320.67 6,244.67 - 1,008.11 - 508.32 6,006,079.62 507,323.02 35.27 1,121.47 MWD (2) 6,649.33 100.24 207.26 6,317.30 6,241.30 - 1,035.18 - 520.82 6,006,052.54 507,310.55 30.10 1,150.94 MWD (2) 6,679.33 102.24 217.70 6,311.44 6,235.44 - 1,059.97 - 536.58 6,006,027.74 507,294.81 34.77 1,180.32 MWD (2) 6,710.30 101.97 229.99 6,304.92 6,228.92 - 1,081.76 - 557.52 6,006,005.93 507,273.90 38.81 1,210.03 MWD (2) 6,740.45 99.07 237.76 6,299.41 6,223.41 - 1,099.21 - 581.45 6,005,988.45 507,250.00 27.10 1,237.77 MWD (2) 6,770.00 97.39 241.24 6,295.18 6,219.18 - 1,114.05 - 606.64 6,005,973.59 507,224.82 12.97 1,264.03 MWD (2) 6,800.27 95.60 244.87 6,291.75 6,215.75 - 1,127.67 - 633.45 6,005,959.94 507,198.03 13.30 1,290.15 MWD (2) 6,830.44 97.45 248.06 6,288.32 6,212.32 - 1,139.64 - 660.92 6,005,947.94 507,170.57 12.16 1,315.27 MWD (2) 6,860.48 97.92 253.04 6,284.30 6,208.30 - 1,149.55 - 688.98 6,005,938.00 507,142.52 16.50 1,338.99 MWD (2) 6,890.66 97.08 257.03 6,280.36 6,204.36 - 1,157.28 - 717.88 6,005,930.25 507,113.63 13.40 1,361.34 MWD (2) • 6,920.63 97.05 261.98 6,276.68 6,200.68 - 1,162.69 - 747.12 6,005,924.80 507,084.40 16.39 1,381.95 MWD (2) 6,950.39 96.15 267.36 6,273.25 6,197.25 - 1,165.44 - 776.54 6,005,922.03 507,054.99 18.21 1,400.43 MWD (2) 6,980.45 95.63 271.66 6,270.17 6,194.17 - 1,165.69 - 806.44 6,005,921.74 507,025.10 14.33 1,417.10 MWD (2) 7,010.63 95.81 276.76 6,267.16 6,191.16 - 1,163.49 - 836.38 6,005,923.91 506,995.16 16.82 1,431.73 MWD (2) 7,045.24 95.66 281.48 6,263.70 6,187.70 - 1,158.03 - 870.37 6,005,929.33 506,961.17 13.58 1,445.88 MWD (2) 7,080.49 95.35 286.01 6,260.31 6,184.31 - 1,149.70 - 904.44 6,005,937.63 506,927.09 12.82 1,457.67 MWD (2) 7,110.73 96.87 284.18 6,257.09 6,181.09 - 1,141.86 - 933.47 6,005,945.43 506,898.05 7.84 1,467.11 MWD (2) 7,140.37 100.74 282.20 6,252.56 6,176.56 - 1,135.18 - 961.98 6,005,952.08 506,869.54 14.63 1,477.22 MWD (2) 7,170.11 99.66 280.37 6,247.29 6,171.29 - 1,129.45 - 990.68 6,005,957.78 506,840.83 7.06 1,488.23 MWD (2) 7,200.46 96.87 278.16 6,242.93 6,166.93 - 1,124.62 - 1,020.32 6,005,962.58 506,811.19 11.68 1,500.51 MWD (2) 7,230.30 93.41 276.38 6,240.25 6,164.25 - 1,120.86 - 1,049.80 6,005,966.31 506,781.72 13.03 1,513.59 MWD (2) 7,260.72 92.58 272.95 6,238.66 6,162.66 - 1,118.39 - 1,080.07 6,005,968.75 506,751.44 11.59 1,528.19 MWD (2) 2/17/2010 10 :29 :28AM Page 3 COMPASS 2003.16 Build 69 Conoco Phillips CortocaPhillips Definitive Survey Report Alaska Company: ConocoPhillips(Alaska) Inc. Local Co- ordinate Reference: 31 - 11 Project: Kuparuk River Unit TVD Reference: 31 -11 @ 76.00ft (31 -1 Site: Kuparuk 31 Pad MD Reference: 31 - 11 @ 76.00ft (31 - 11) Well: 31 - North Reference: TRUE Weilbore: 31 - 11 Survey Calculation Method: Minimum Curvature Design: 31 - Database: EDM Alaska Prod v16 Survey Map Map Vertical MD . Inc Azi TVD TVDSS +N /-S +E/-W Northing Easting °DLS Section s urvey T Name Annotation (ft) ( °) ' ( °) (ft) (ft) (ft) (ft) (ft) (ft):.. (7700') (ft) 7,290,70 92.64 269.05 6237.30 6,161.30 - 1,117.87 - 1,110.01 6,005,969.24 506,721.51 13.00 1,544.23 MWD (2) . 7,320.97 94,36 265.24 6,235.45 6,159.45 - 1,119.37 - 1,140.18 6,005,967.70 506,691.34 13.79 1,562.08 MWD (2) 7,350,59 95.69 261.40 6,232.85 6,156.85 - 1,122.80 - 1,169.48 6,005,964,24 506,662.05 13.67 1,581.07 MWD (2) 7,380.72 95.66 257.56 6,229.87 6,153.87 - 1,128.28 - 1,198.95 6,005,958.74 506,632.58 12.68 1,601.86 MWD (2) 7,410.42 95.29 253.90 6,227.04 6,151.04 - 1,135.56 - 1,227.60 6,005,951.42 506,603.95 12.33 1,623.71 MWD (2) 7,440.37 93.78 251.57 6,224.67 6,148.67 - 1,144.42 - 1,256.10 6,005,942.53 506,575,45 9.25 1,646.80 MWD (2) 7,470.46 90.15 250.38 6,223.64 6,147.64 - 1,154.23 - 1,284.53 6,005,932.70 506,547.04 12.69 1,670.62 MWD (2) 7,500.60 88.93 246.89 6,223.88 6,147.88 - 1,165.20 - 1,312.59 6,005,921.70 506,518.99 12.27 1,695.23 MWD (2) 7,530.73 88.83 242.31 6,224.47 6,148.47 - 1,178.12 - 1,339.80 6,005,908.75 506,491.80 15.20 1,720.99 MWD (2) 7,560.74 88.71 237.77 6,225.12 6,149.12 - 1,193.10 - 1,365.78 6,005,893.75 506,465.84 15.13 1,747.80 MWD(2) 7,590.54 88.28 234.49 6,225.90 6,149.90 -1,209.70 - 1,390.52 6,005,877.12 506,441.12 11.10 1,775:27 MWD (2) 7,620.46 87.12 230.87 6,227.10 6,151.10 - 1,227.82 - 1,414.29 6,005,858.98 506,417.37 12.70 1,803.48 MWD (2) 7,650.55 86.44 226.29 6,228.79 6,152.79 - 1,247.69 - 1,436.81 6,005,839.09 506,394.88 15.36 1,832.46 MWD (2) 7,680.54 87.61 221.76 6,230.35 6,154.35 - 1,269.22 - 1,457.62 6,005,817.54 506,374.09 15.58 1,861.89 MWD (2) 7,710.64 88.34 217.70 6,231.41 6,155.41 - 1,292.35 - 1,476.84 6,005,794.39 506,354.90 13.70 1,891.78 MWD (2) 7,740.62 88.13 212.93 6,232.34 6,156.34 - 1,316.79 - 1,494.16 6,005,769.93 506,337.61 15.92 1,921.72 MWD (2) 7,770.53 87.51 208.66 6,233.47 6,157.47 - 1,342.46 - 1,509.45 6,005,744.25 506,322.34 14.42 1,951.57 MWD (2) 7,800.57 87.48 204.78 6,234.79 6,158.79 - 1,369.26 - 1,522,95 6,005,717.44 506,308.87 12.90 1,981.37 MWD (2) 7,830.68 88.53 200.71 6,235.84 6,159.84 - 1,397.01 - 1,534.58 6,005,689,68 506297.27 13.95 2,010.94 MWD (2) • 7,850.62 90.25 198.35 6,236.05 6,160.05 - 1,415.80 - 1,541.24 6,005,670.89 506,290.63 14.64 2,030.30 MWD (2) 7,880.80 89.63 194.82 6,236.08 6,160.08 - 1,444.72 - 1,549.86 6,005,641.96 506,282.05 11.88 2,059.18 MWD (2) 7,910.63 91.04 190.91 6,235.91 6,159.91 - 1,473,79 - 1,556.50 6,005,612.88 506,275.44 13.93 2,087.11 MWD (2) 7,940.47 92.61 187.10 6,234.95 6,158.95 - 1,503.24 - 1,561.16 6,005,583.43 506,270.80 13.80 2,114.27 MWD (2) 7,970.51 92.46 182.98 6,233.63 6,157.63 - 1,533.13 - 1,563.80 6,005,553.54 506,268.20 13.71 2,140.68 MWD (2) 8,000.69 92.70 178.89 6,232.27 6,156.27 - 1,563.27 - 1,564.29 6,005,523.40 506,267.74 13.56 2,166.12 MWD (2) 8,033.32 93.96 174.95 6,230.37 6,154.37 - 1,595.79 - 1,562.54 6,005,490.89 506,269.52 12.66 2,192.31 MWD (2) 8,065.60 93.44 170.50 6,228.29 6,152.29 - 1,627.74 - 1,558.46 6,005,458.95 506,273.63 13.85 2,216.73 MWD (2) 8,095.40 93.10 166.65 6,226.59 6,150.59 - 1,656.89 - 1,552.57 6,005,429.80 506,279.55 12.95 2,237.84 MWD (2) 8,130.42 94.15 161.51 6,224.37 6,148.37 - 1,690.49 - 1,542.99 6,005,396.22 506,289.17 14.95 2,260.62 MWD (2) 8,160.82 95.01 158.51 6,221.94 6,145.94 - 1,718.97 - 1,532.63 6,005,367.76 506,299.56 10.24 2,278.69 MWD (2) 8,190.58 96.30 155.10 6,219.01 6,143.01 - 1,746.18 - 1,520.97 6,005,340.56 506,311.25 12.20 2,295.00 MWD (2) 2/17/2010 10:29:28AM Page 4 COMPASS 2003.16 Build 69 ConocoPhillips CoriocoPhiiiips ; Definitive Survey Report HUGHES Alaska' Company: { ConocoPhillips(Alaska) Inc. Local Co- ordinate Reference: 31 - 11 Project: Kuparuk River Unit TVD Reference: 31 -11 @ 76.00ft (31 -11) Site: Kuparuk 31 Pad MD Reference: 31 -11 @ 76.00ft (31 -11) Well: 31 - 11 North Reference: TRUE Welibore: 31 -11 Survey Calculation Method: Minimum Curvature Design : 31 - 11 Database: EDM Alaska Prod v16 Survey Map Map Vertical MD Inc' Azi TVD TVDSS +Nt -S +!/IV Northing Fasting °DLS 'Section Survey Tool Name Annotation O °) {o) (ft) (ft) {R) (ft) {ft) (ft) (f,1fltT) (ft) 8,220.83 96.40 151.65 6,215.66 6,139.66 - 1,773.05 - 1,507.50 6,005,313.70 506,324.74 11.34 2,310.02 MWD (2) • 8,250.79 96.24 154.56 6,212.36 6,136.36 - 1,799.61 - 1,494.03 6,005,287.16 506,338.24 9,67 2,324.78 MWD (2) 8,280.83 96.37 158.76 6,209.06 6,133.06 - 1,827.02 - 1,482.20 6,005,259.77 506,350.09 13.90 2,341.16 MWD (2) 8,310.81 95.56 163.25 6,205.95 6,129.95 - 1,855.20 - 1,472.50 6,005,231.60 506,359.82 15.14 2,359.35 MWD (2) 8,340.52 95.13 166.95 6,203.18 6,127.18 - 1,883.78 - 1,464.90 6,005,203.03 506,367.46 12.48 2,379.03 MWD (2) 8,370.64 92.86 169.33 6,201.08 6,125.08 - 1,913.19 - 1,458.72 6,005,173.63 506,373.66 10.91 2,400.19 MWD (2) 8,400.38 91.14 172.50 6,200.04 6,124.04 - 1,942.53 - 1,454.03 6,005,144.30 506,378.38 12.12 2,422.10 MWD (2) 8,430.66 90.58 176.31 6,199.59 6,123.59 - 1,972.66 - 1,451.08 6,005,114.18 506,381.37 12.72 2,445.64 MWD (2) 8,460.17 88.92 178.74 6,199.71 6,123.71 - 2,002.14 - 1,449.81 6,005.084.70 506,382.67 9.97 2,469.55 MWD (2) 8,490.40 89.57 182.02 6,200.11 6,124.11 - 2,032.36 - 1,450.01 6,005,054.48 506,382.50 11.06 2,494.89 MWD (2) 8,520.36 89.45 186.73 6,200.37 6,124.37 - 2,062.22 - 1,452.29 6,005,024.62 506,380.25 15.73 2,521.08 MWD (2) 8,550.31 90.25 191.81 6,200.45 6,124.45 - 2,091.77 - 1,457.11 6,004,995.07 506,375.46 17.17 2,548.41 MWD (2) 8,580.26 89.26 195.82 6,200.58 6,124.58 - 2,120.85 - 1,464.26 6,004,965.99 506,368.34 13.79 2,576.62 MWD (2) 8,610.53 88.62 200.37 6,201.14 6,125.14 - 2,149.61 - 1,473.66 6,004,937.22 506,358.97 15.18 2,605.81 MWD (2) 8,640.34 89.36 204.84 6,201.66 6,125.66 - 2,177.12 - 1,485.12 6,004,909.70 506,347.55 15.20 2,635.08 MWD (2) 8,673.50 88.80 209.77 6,202.19 6,126.19 - 2,206.57 - 1,500.32 6,004,880.24 506,332.38 14.96 2,668.04 MWD (2) 8,700.45 89,69 213.59 6,202.55 6,126.55 - 2,229.50 - 1,514.47 6,004,857.30 506,318.25 14.55 2,694.97 MWD (2) 8,730.36 89.72 218.22 6,202.70 6,126.70 - 2,253.72 - 1,532.01 6,004,833.06 506,300.74 15.48 2,724.84 MWD (2) 8,760.32 89.94 222.34 6,202.79 6,126.79 - 2,276.57 - 1,551.37 6,004,810.19 506,281.40 13.77 2,754.58 MWD (2) • 8,790.30 90.31 226.72 6,202.73 6,126.73 - 2,297.93 - 1,572.39 6,004,788.81 506,260.41 14.66 2,783.99 MWD (2) 8,820.21 88.83 230.75 6,202.95 6,126.95 - 2,317.66 - 1,594.87 6,004,769.06 506,237.96 14.35 2,812.82 MWD (2) 8,849.79 88.19 235.11 6,203.72 6,127.72 - 2,335.48 - 1,618.45 6,004,751.22 506,214,39 14.89 2,840.68 MWD (2) 8,880.05 87.27 237.53 6,204.92 6,128.92 - 2,352.24 - 1,643.61 6,004,734.43 506,189.25 8.55 2,868.53 MWD (2) 8,922.38 83.29 235.01 6,208.40 6,132.40 - 2,375.66 - 1,678.69 6,004,710.98 506,154.20 11.12 2,907.38 MWD (2) 8,950.54 82.94 230.75 6,211.78 6,135.78 - 2,392.53 - 1,700.98 6,004,694.09 506,131.94 15.07 2,933.73 MWD (2) 8,980.43 86.68 228.11 6,214.48 6,138.48 - 2,411.88 - 1,723.58 6,004,674.71 506,109.35 15.29 2,962.33 MWD (2) 9,010.06 86.06 223.21 6,216.36 6,140.36 - 2,432.54 - 1,744.72 6,004,654.03 506,088.23 16.64 2,991.22 MWD (2) 9,040.07 84.90 219.51 6,218.73 6,142.73 - 2,454.99 - 1,764.49 6,004,631.56 506,068.49 12.88 3,020.84 MWD (2) 9,070.06 85.91 214.72 6,221.13 6,145.13 - 2,478.82 - 1,782.52 6,004,607.71 506,050.49 16.27 3,050.66 MWD (2) 9,100.03 84.25 211.14 6,223.70 6,147.70 - 2,503.88 - 1,798.75 6,004,582.64 506,034.29 13.13 3,080.51 MWD (2) 9,130.02 84.00 207.59 6,226.77 6,150.77 - 2,529.88 - 1,813.38 6,004,556.63 506,019.69 11.80 3,110.27 MWD (2) 2/17/2010 10 :29 :28AM Page 5 COMPASS 2003.16 Build 69 ♦•f t ConocoPhillips CornocoP Llhhps Definitive Survey Report HUGFIES Alaska Company: ConocoPhillips(Alaska) Inc. Local Co- ordinate Reference: 31 -11 Project: Kuparuk River Unit TVD Reference: 31 - 11 @ 76.00ft (31 - 11) Site: Kuparuk 31 Pad MD Reference: 31 -11 @ 76.00ft (31 -11) Well: 31 -11 North Reference: TRUE Welibore: 31 -11 Survey Calculation Method: Minimum Curvature Design: 31 - 11 Database: EDM Alaska Prod v1 6 Survey Map Map - Vertical MD Inc Ali TVD TVDSS +NkS ( +E1.W Northing Easfing Section Survey Tool Name Annotation • (ft) (o) (') (ft) . (ft) • (ft) (ft) (ft (ft) (°/100') (ft) 9,160,07 84.62 203.52 6,229.75 6,153.75 - 2,556.85 - 1,826.27 6,004,529.65 506,006.82 13.63 3,139.88 MWD (2) • 9,189.99 84.40 199.60 6,232.62 6,156.62 - 2,584.54 - 1,837.22 6,004,501.95 505,995.91 13.06 3,169.03 MWD (2) 9,217.80 87.39 196.39 6,234.61 6,158.61 - 2,610.92 - 1,845.78 6,004,475.57 505,987.37 15.75 3,195.76 MWD (2) 9,250.24 87.97 192.55 6,235.92 6,159.92 - 2,642.30 - 1,853.88 6,004,444.18 505,979.31 11.96 3,226.42 MWD (2) 9 90.80 189.12 6,236.24 6,160.24 - 2,671,61 - 1,859.49 6,004,414.86 505,973.73 14.89 3,253.99 MWD (2) 9,310.14 94.95 185.57 6,234.74 6,158.74 - 2,701.36 - 1,863.33 6,004,385.12 505,969.93 18.17 3,280.93 MWD (2) 9,340.20 98.01 182.88 6,231.34 6,155.34 - 2,731.14 - 1,865.53 6,004,355.34 505,967.76 13.52 3,307.01 MWD (2) 9,370.82 100.24 179.37 6,226,49 6,150.49 - 2,761.36 - 1,866.12 6,004,325.12 505,967.19 13.46 3,332.57 MWD (2) 9,397.55 100,87 176.45 6,221.59 6,145.59 - 2,787.62 - 1,865.17 6,004,298.87 505,968.18 10.99 3,353.97 MWD (2) 9,437.00 100.87 176.45 6,214.15 6,138.15 - 2,826.28 - 1,862.77 6,004 260 21 505,970.61 0.00 3,384.94 PROJECTED to TD • 2/17/2010 10:29:28AM Page 6 COMPASS 2003.16 Build 69 • • • sun ALAsEn SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Jill Long Wells Engineer ConocoPhillips Alaska, Inc. 09-( P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 31-11L1 Sundry Number: 310 -177 Dear Ms. Long: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, ti Daniel T. Seamount, Jr. /� Chair DATED thi§42 day of June, 2010. Encl. • `' b ,to STATE OF ALASKA (,'t ALAS•IL AND GAS CONSERVATION COMMIS APPLICATION FOR SUNDRY APPROV 0 AAC 25.280 1. Type of Request: Abandon r Rug for Redrill rf frate New Pool r Repair well Change Approved Program r Suspend Sus p Rug Perforations / i �' I� / 4 Perforate r Pull Tubing r Time Extension r Operational Shutdown fl Re -enter Susp. Well r Stimulate r Alter casing r r O ther: 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: p p ConocoPhillips Alaska, Inc. Development 17 • Exploratory r 209 -121 • 3. Address: Stratgraphic r Service 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50 029 - 21932 - 60 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes r No 31-11L1 • 9. Property Designation: 10. Field /Pool(s): ADL 25523, 25631 Kuparuk River Field / Kuparuk River Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9437 • 6214 • 6421' 6230' 6422' Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 116' 116' SURFACE 3348 9.625 3383' 3383' PRODUCTION 6375 7 6408' 6141' L1 LINER 1847 2.375 9438' 6214' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): none none 3.5" L -80 6408' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - BAKER 84 -SAB -40X32 RETAINER PROD. PACKER MD= 6146 TVD= 5977 SAFETY VLV - Camco 3 1/2" x 2.813" 'X' Profile TRMAXX - 5E SCSSSV MD =2212 TVD =2212 12. Attachments: Description Summary of Proposal ;✓ 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch Exploratory De velopment • Pv Service r 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 6/22/2010 Oil r Gas r WDSPL r Suspended 17 : 16. Verbal Approval: Date: WINJ r GINJ r WAG r Abandoned Commission Representative: GSTOR r SPLUG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jill Long © 263 -4093 Printed Name Jill Long Title: Wells Engineer Signature ---)44--Le-, Phone: 263 -4093 Date 0(o /t /) 0 Commission Use Only Sundry Number:5 J 0 177 Conditions of approval: Notify Commission so that a representative may witness Plug Integrity ir7 BOP Test r Mechanical Integrity L Location Clearance RECEIVED Other: * 5z es- lI S T z 43 a P ,-2s rs.. 4nnK.1.0-A. es f' Cis--.) JUN 1 1 2010 Subsequent Form Required: /D'" "107 Alaska Oil & Gas Cons. Commiss on Anchorage )0 �' APPROVED BY /' �j/ //Q Approved by: V COMMISSIONER THE COMMISSION Date: (p (L � Form 1Ar��0�3.f;2�y ser Q1A A L Submit inpiiplicate ,2 tt�1SSLUlMM..77 �w�117/ i iV� ,' 1 /5l • • Sundry Application for Plugging Perforations KRU 31 -11 and 31-1 1 L1 Objective The attached Sundry application requests permission to plug the perforations in the 31 -11 and 31 -11 L1 wellbores. The plugging is planned in conjunction with the drilling of three, A -sand CTD sidetracks described below. Well History Well 31 -11 was originally drilled and completed as an A -sand producing, single completion well in 1989 with 2- 7/8" tubing. A workover was performed in May 2009 to replace leaking tubing. At that time the well had already been identified as a CTD candidate so the tubing was upsized from 2 -7/8" to 3 -1/2" and a subsurface safety valve (SSSV) was installed in preparation for the sidetracks. The original objective of the CTD sidetracks was to drill three lateral sidetracks out of the 31 -11 parent wellbore targeting the Al, A2 and A3 sands to access reserves from currently undrained areas to the south. The laterals were planned and permitted as 3I-11L1 (PTD# 209 - 1210), 31-11L1-01 (PTD# 209 - 1220), and 3I-11L1-02 (PTD# 209 -1230) because the perforations in the parent wellbore were going to remain open to production. Nabors CDR2 rigged up on 31 -11 in January 2010 and began drilling operations. Unfortunately, after drilling the 3I -11L1 lateral and partially lining what had been drilled, the window became inaccessible. Drilling operations were suspended on February 13, 2010, to diagnose the problem with the window and acquire additional 13.1 ppg potassium formate completion fluid. Laterals 31- 11L1 -01 (PTD# 209 -1220) and 31- 11L1 -02 (PTD# 209- 1230) were neither drilled or completed prior to rig release. Post -rig diagnostics confirmed the whipstock had released and moved downhole. After completing diagnostics on the window, 3I-11L1 was opened to flow to tanks in an attempt to bring the well pressure down before returning with the rig again. Initial production tests had —850 BLPD at 62.4% WC, 21.5 API, 0.75% solids at 950 WHP. As drawdown on the well was increased, the openhole lateral eventually collapsed and the tubing filled with solids. A fill cleanout was performed in April 2010 and the well has remained shut -in since then. Plan Forward The plan forward for this well is to set a plug in the 3 -1/2" tubing above the previously drilled window prior to attempting the CTD sidetracks again. This will isolate the 31 -11 parent wellbore perforations in addition to the 31- 11 L1 lateral and prevent solids production which could potentially plug the tubing again and prohibit production from the new sidetracked laterals. A whipstock will also be set pre -rig. Once the CTD rig arrives, a dual string window (3 -1/2" x 7 ") will be milled from which the three lateral sidetracks will then be drilled. The laterals will be named and permitted as 3I -11A, 3I- 11AL1, and 31- 11AL2. c , i Page 1 of 2 6/11/2010 Sundry • • - ry Application for Plugging Perforations KRU 31 -11 and 31 11 L1 Operational Outline Pre -Rig Work Remaining 1. Tag fill and obtain a SBHP survey 2. Set a cast iron bridge plug in the 3.5" tubing at —6406' 3. Set a 3.5" monobore whipstock at —6397' 4. Prepare wellsite for rig arrival. l Rig Work fi 1. MIRU Nabors CDR2 -AC rig using 2" coil tubing. NU 7- 1/16" BOPE, test. 5 (j - tit 2. 31 -11A Lateral (A2 Sand) a. Mill 2.80" 2- string window with high -side orientation at 6397' MD b. Drill 2.70" x 3" bi- center lateral in the A2 sand PTO c. Load well with kill weight fluid. Run 2%" slotted liner with an aluminum liner -top billet 3. 31 -11AL1 Lateral (Al Sand) a. Kick off of the aluminum billet b. Drill 2.70" x 3" bi- center lateral in the Al sand c. Load well with kill weight fluid. Run 2%" slotted liner with an aluminum liner -top billet 4. 31 -11AL2 Lateral (A3 Sand) a. Kick off of the aluminum billet b. Drill 2.70" x 3" bi- center lateral in the A3 sand c. Load well with kill weight fluid. Run 2%" slotted liner from TD up to 6385' MD, inside the 3'/2" tubing 5. Freeze protect. ND BOPE. RDMO Nabors CRD2 -AC. Handover to Production group. Post - Rig Work 1. Obtain SBHP 2. Flowback for well cleanup 3. Begin production Page 2 of 2 6/11/2010 • • Page 1 of 1 Schwartz, Guy L (DOA) From: Long, Jill W [Jill.W.Long @conocophillips.com] Sent: Thursday, June 03, 2010 3:48 PM To: Schwartz, Guy L (DOA) Subject: Withdraw Drilling Permits #209 -1220 and #209 -1230 D ZA Guy - The purpose of this email is to formally request to withdraw drilling permits #209 -1220 and #209 -1230 that were approved for planned coiled tubing drilling (CTD) sidetracks from Kuparuk producing well 31 -11. In October 2009, Permit to Drill (PTD) applications were approved for three CTD sidetracks from 31 -11: 3I-11L1 (PTD# 209 - 1210), 3I- 11L1 -01 (PTD# 209 - 1220), and 3I- 11L1 -02 (PTD# 209 - 1230). The objective of these sidetracks was to access unswept reserves in the Al, A2, and A3 sands south of 31 -11. Work on those sidetracks began January 24, 2010, with the arrival and rig up of CTD rig, Nabors CDR2. After drilling 3I-11L1 and running the liner from TD up to the planned kickoff point for 3I- 11L1 -01, the window became inaccessible. Without access to the window the only solution for meeting the objectives of the project was to mill a second window and resume drilling all three laterals from there. At that time however, there was a low supply of potassium formate on the slope which was needed for use as the overbalanced completion fluid. Therefore, CTD operations were suspended until the potassium formate supply was sufficient for completing all three sidetracks on 31 -11. Nabors CDR2 rigged down and moved off the well on February 14, 2010. After the rig moved off, the well was put on production. The tubing eventually plugged off with solids produced from the unlined, openhole section of 3I -11L1 and was shut -in. A fill cleanout was performed on April 22, 2010, and the well has remained shut -in since then awaiting future work. The plan forward for 31 -11 is to set a plug in the 3 -1/2" tubing above the previously drilled window and attempt the CTD sidetracks again from a second window. The plug will isolate the 3I -11L1 lateral and prevent solids from plugging off production from the future CTD sidetracks. By plugging the 3I-11L1 lateral, the 31 -11 parent wellbore perforations will be isolated as well. The reservoir targets and objectives for the future CTD sidetracks have not changed, nor have the planned rig operations. The only difference in the drilling program is that the parent wellbore perforations will no longer be open to production after drilling the laterals. Therefore, all three CTD sidetrack laterals will have different names (3I -11A, 31- 11AL1, 3I- 11AL2) and require new drilling permits. Since the permitted laterals 31- 11L1 -01 and 31 -11 L1 -02 were not drilled and are no longer planned, the drilling permits for those laterals will not be used. Therefore, please let this email serve as ConocoPhillips' request to withdraw drilling permits #209 -1220 and #209 -1230. If you have questions please let me know. Sundry and PTD applications for the future work described above are being prepared and will be submitted soon. Thank you, Jill Long ConocoPhillips Alaska Drilling and Wells Office: 907 - 263 -4093 Cell: 907 - 230 -7550 Fax: 918- 662 -6330 9/22/2010 Page 1 of 2 • Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Thursday, May 06, 2010 2:10 PM To: 'Long, Jill W Subject: RE: 31 -11 CTD Re -drill Permitting Guidance Jill, As we discussed on the phone... my recommendations are as follows: 1) Submit two separate 403 sundries to abandon the 31 -11 Motherbore and 3I-11L1 lateral. 2) Request to withdraw the existing drilling permits for 31-11L1-01 and 3I-11L1-02 3) Submit three new PTD applications for 3I -11A , 3I -11AL1 and 3I- 11AL1 -01 If you have any questions please call me back. Thanks, Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Long, Jill W [mailto:Jill.W.Long @conocophillips.com] Sent: Tuesday, April 27, 2010 11:31 AM To: Schwartz, Guy L (DOA) Cc: Allsup- Drake, Sharon K Subject: 3I -11 CTD Re -drill Permitting Guidance Guy - To follow up with our phone conversation this morning, will you please take a look at Kuparuk producing well 31- 11 and let us know how the State would like us to proceed with sundry and permit to drill applications associated with future work. In summary, here is our current plan forward on the well: 1) Permanently abandon the parent wellbore perforations in 31 -11 as well as the lateral 31 -11 L1 that was partially completed. At this time, we are considering setting a cast iron bridge plug above the previously drilled window prior to rig arrival. 2) Milling a second window (approximately 12' higher than the previously drilled window) and drilling three laterals with the same reservoir targets and objectives as the three previously permitted laterals that were unable to be drilled due to the issues encountered with re- accessing the lower window. Attached is a current proposed schematic. I understand the naming conventions may change from what is shown in this schematic but the lateral objectives and general, overall picture of what the final product will be after the "re- drill" project will remain the same. Please let me know what questions you have. Thanks in advance for your help on this, Jill Long ConocoPhillips Alaska Drilling and Wells Office: 907 - 263 -4093 5/6/2010 1 ' ip 31 -11 Proposed CTD Sidetrack Revision Updated: 27- Apr -10 42 - (Z 1 Camco TRMAXX -5E SSSV @ 2212 MD (2.813" min ID, X- profile) 3-1/2", 9.3# L -80 EUE 8rd -Mod Tubing to surface KEY / i • 7-/o) Equipment and perforations set in '-�/ lit 3-1/2" Camco MMG gas 1611 mandrels (5) @ parent wellbore � — 2512', 3702', 4760', 5668', & 6074' Equipment set and lateral drilled 16" 62# H-40 shoe during first CTD project @ 116' MD YAW X' landing nipple (516123' MD (2.813" min ID) Equipment set and laterals drilled I. Baker 3-1/2" seal assembly 6131' - 6143' MD during second CTD project 9 -5/8" 36# J -55 80-40 PBR at 6132' - 6145' shoe @ 3383' MD ■ Baker KBH Anchor Seal Assy at 6145' MD Baker SAB 40-32 packer @ 6146' MD El 'X' landing nipple @ 6156' MD (2.813" min ID) Whipstock @ 6397' 31 - 11A L1 - MD Holes shot in 3 - 1/2" straddle at - 6408' - 6413' & 6213' MD (A3 sand, wp04) Kickoff from 31 -11 AL1 @ 7300' (Baker monobore Full deployment sleeve @ 6300' whipstock) Baker F1 permanent packer @ 6422' MD (e -line set) II 80-40 Sealbore extension (6426- 6430') Solid liner from 6300 - 6450' Slotted liner from 6450' to TD III 3-1/2" straddle cemented in place • F �:. s p*; 'D' landing nipple @ 6433' MD (2.750" min ID) TD @ 9090' .f`�=" WLEG @6438'MD Cast Iron Bridge Plug Y @ - 6406 - FISH: 3-1/2" '4 `. - -- --- -- ----- -- ----- _ - monobore 31 -11A whipstock at 6422' (A sand, wpto) (TOWS) �• - �---'- - -- ---- ---- ------ --- �. � ..°�.! - - - � Kickoff from 31.11 @ 6397' liner top billet @ 7400' 1 —,- - Slotted liner from 7400' to TD FISH: 3-1/2" p -1 TD @ 9200' monobore I .° is l .w ; whipstock @ ■ : - - unknown depth A sand .11MITIF^ \ A3: 643T 7' - - 6 6454' -=`----- , A2: 6457' -6486' — -- (A2 sand) 31 -11AL1 Kickoff from 31 - 11 @ 6409' (A1 sand, wp05) Al: 6494' - 6503' Kickoff from 31 -11 A @ 7400' - Short deployment sleeve @ 7590' Liner top billet @ 7300' Slotted liner from 7590' to TD Slotted liner from 7300' -TD TD @ 9437' TD @ 9200' • 7" 26# J -55 shoe @ 6550' MD FIliiill Company ConocoPhillips, Alaska, Inc. APR 2 3 2010 BAKER Well Name 31-11L1 HUGHES 041 a CiP,3 Govc%, Coirrniqmloo Date 3/19/2010 Pindrfirogn ENTEQ ConocoPhillips Alaska Greater Kuparuk Area*** Data Distribution RECIPIENTS No other distribution is allowed without OH FINAL OH FINAL written approval from ConocoPhillips Image files and/or Digital Data contact: Lisa Wri • ht, 907 263-4823 hardco • prints 1 ConocoPhillips Alaska, Inc. ill Sharon Allsup-Drake Drilling Tech, ATO-1530 ConocoPhillips Alaska, Inc. 1 Hardcopy Print NSK Wells Aide, NSK 69 , ATTN: MAIL ROOM 700 G Street, Anchorage, AK 99501 , ConocoPhillips Alaska, Inc. Ricky Elgarico 1 Graphic Image 1 Disk*/ p - P... _t.-- , ' e Z.! File**/*** Electronic : 700 G Street, CGM / TIFF LIS Anahora4je ftp://b2bftp.conocophillips.com **** AOGCC 1 Hardcopy Print, ( , ' Christine Mahnken 1 Graphic image file 1 Disk*/ I t 333 West 7th Ave, Suite 100 1 in lieu of sepia** Electronic Anchorage, Alaska 99501 CGM / TIFF LIS 410 BP 1 Hardcopy Print, 1 Petrotechnical Data Center, MB33 1 Graphic image file 1 Disk*/ - , David Douglas in lieu of se pi a ** Electronic P.O. Box 196612 CGM / TIFF LIS Anchorage, Alaska 99519-6612 CHEVRON/KRU REP 1 Hardcopy Print, Glenn Fredrick 1 Graphic image file 1 Disk"/ P.O.Box 196247 in lieu of sepia** Electronic Anchorage, Alaska 99519 CGM / TIFF LIS Brandon Tucker, NRT State of Alaska; DNR, Div. of Oil and Gas 1 Disk*/ 550 W. 7th Ave, Suite 800 Electronic rr Anchorage, Alaska 99501-3510 LIS ., ... _ _ . ......... , DS Engineer / Rig Foreman , TOTAL . Hardcop Prints 4 , t Page 1 of 4 31 -11 Plan Forward ' r . 1 ...,Y . „ , . , 65.! y , 6389' """' 3 -1/2" Tubing Joint 1, i 6130 - #- - -_ - -- 4 6398' Top of Whipstock 4-4 4.4 i . 1 1 ' ___ ... M 6400' ` ` % a 1 I i 1 1 4-- - Mill contacts 7" — 4' below TOWS = 6402' I - I 1 4 . C4 , ` ' , 4 — . - 6403' Bottom of 3 -1/2" Window 6407' Bottom of Whipstock 14J 4--- _ i l l 6409' Top of Window ► x 4 6408' Bottom of 7" Window --► ■ • • • • • iiii011*V•IT• • Mhu 6410' 7" Casing Joint I . • • I 6408' -6413' perf holes • �`� 1 ; 1 Original window • 1 15GjT_ 6420' Bottom of Window • n 6420 W 6420' Baker GBH Seal Assy. j ! X 6422' Baker F1 P - � - i / Top of A5 "" 1 S-. b1E 6430' • 6425' -6430' Ext. Seal Bore .- 640 7" Casing Joint i 1 6433' D- nipple (2,75" ID) Fallen whipstock - - naeoas acasxa i 617a 6438' SOS w/ WLEG all ,,An 2R 31-11 Plan Forward 0e 5,G �3 ; c c J 753C 3CCG 35CC� vt C�3 I l 1 I I I I 1 1 f 1 I I 1 1 1 1 1 I I 1 1 1 1 1 1 1 1 I 1 1 1 1 1 I 1 1 l I 1 1 1 I I 1 1 1 1 I I 1 • 530 1GC1C1 ,5110 2300 2530 33C0 FAULT ,4: , _ FAULT : 33 ff DTS 6ffDT FAULT 2: FAULT 1: 143 ff DTE i . 7 ft TW? ---:` - - -- - ..,. lii, _ - NABORS ALASKA CIA 2111 31-11 CTD Planned X-section C 0 6400 6900 7400 7900 8400 8900 I 0 500 1000 1500 2000 2500 — • 6050 o��� M� �����I�•� �I��I���- ��� _- -----_'--_ _- -_ _ 11111111111 : ::1 — . 6 —.._ _____ _---_-1----7- —,,_i. --_--___----= ------_-___71:- ,4 �.. - - -- . -.-- 6200 ' i • A3 Target 6250 r 0 A2 Target • A' Target NABORS ALASKA CIA 2111 i 02 311.1 1 Li x.. c.......p. J i - :....c.,, ..... .... r11 ,r1C■11■ "AAA V ■JJ ........//d ...././uf ..../ow I 1 1 1 I I I 1 1 1 I I I 1 I 1 1 / 1 I I 1 1 1 1 1 I I I r r 1 1 I 1 1 L 1 1 I 1 1 1 1 I 1 I I 1 I 1 1 i 1 i 1 i • 500 1::: ...... 3000 .... -- .. .... ...... FAULT 4: FAULT 3: 33 ft DTS 6 ff DTS FAULT 5: FAULT 2: 18 ft DTN FAULT 1: 43 ff DTE 7 ft fiTVi? .., - . ...._ :„:.... ....... .„ . A k _ . ...._ _ . . . . . _ • - - ., , - - - - - - - - - - - ---- - - - - ---------------- - . \ • i r..., \ - MIMI !111.11111111 - 1 NAROR Cifq, 211C f 31-IILI Schematic ______ 1 , 1 I I -- ( I C3mCA TR %IAXX -SE SSSV a 22`2 \19 (2 813' rrf ;D. X-cr'otue L ? -'•_' 9.3=1.-82 EUE 8rd -M00 Tubing :o surface E E_c -I -4: S' :E 1111 4.r Camcc 1/MG gas Illl mandrels (5) :512 3 4760', 5658', d 6074 0 9-51 36a J -` -5 s•1oe ' g 3383 1/3 IIII _roll - 110..-- III . arlIry nlppte ® 6123' lD (2.813' mtn ID) Sakes 3.112" seal assembly 6131 - 5143' MD :0-40 PIR a: 6137 - 6145' 'Sake- K131- Moor Sea! Asay at 6145' MD Sake- SA9 40 -32 packer a 6146' MD NM I x land ng nipple 6156' MO (2.613' mlr 101 - :les snot In 3.1.2' stud:: a a1 -.-54:s-643 ' b Baker F1 permanent pacer g 6422 V= - e' ?i - 80-40 Seait:re extensor 15425'-5412' r 3-1 sxaoa a D' tardirg nip. e g 6x33' M3 12 mtn ID) cemented In place _ _ +%_ES g 6436 I/O 1 -1'2' Tar bo A ilpsto',:k. al 54:2'i • - --:::-. : -.-..: . .:"...-.:-. , . __ . / /// � — It TD a 9437• (A2 A said cerrs / sandy A3' 6437 - 5454' A2 6457 -6455' r: _ :: -3 6' 1 otted ' A 6494 - 6527 - ?- - : - 7592 7' 2E= - -55 Enoe 0 6550 1/2 NAAOAS AL ASKA Cliq 2110 STATE OF ALASKA 0 ALASAIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair w elt r Rug P r Stimulate r Other report P Tubing operations Alter Casing r g I `�` Perforate New P I"® W r Time Ex tension "' Change Approved Prrogram -" Operat. Shutdow n IV 1.j1 ° Perforate r Re -enter Suspended Well r 2. Operator Name: 4. Current Well Status: N§. Permit to Drill Number: ConoCoPhillips Alaska, Inc. Development Exploratory r 209-121 3. Address: \. API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic Service 50- 029-21932.60 7. Ftstzerty Designation: 8. Well Name and N, amber: ADL 25523, 25631 \ 3I-11L1 9. Field /Pool(s):\ Kuparuk River Field / Kuparuk River Oil Pool 10. Present Well Condition Summary: Total Depth measured 9437 feet Plugs (measured) None true vertical 6214 feet Junk (measured) 6422 Effective Depth measured 6421 feet Packer (measured) 6146 true vertical 6230 feet (true vertucal) 5977 Casing Length Size MD TVD Burst .Collapse CONDUCTOR 80 16 116 116' SURFACE 3348 9.625 3383 3383' PRODUCTION 6375 7 6408 6141' RECEIVED 11 LINER 1847 2.375 9437 6214 L• MAR 1 6 2010 Perforation depth: Measured depth: none Alaska 011 & Gas Cons. Commission True Vertical Depth: none Anchorage Tubing (size, grade, MD, and TVD) 3,5" Packers & SSSV (type, MD, and TVD) PACKER - BAKER 84-SAB -40X32 RETAINER PROD. PACKER @ 6146 MD and 5977 TVD Camco TRMAXX -5E SSSV, MD =2212 TVD =2212 11. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation si Subsequent to operation 320 -- 530 -- -- 13. Attachments 14. Well Class after proposed work: Copies of Logs and Surveys run Exploratory r Development Service 15. Well Status after work: Oil 17 Gas r WDSPL r Daily Report of Well Operations XXX GSTOR r WAG r GASINJ r WINJ r SPLUG 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 310 -053 Contact James Ohlinger @ 265 -1102 Printed Name James Ohlinger Title Coiled Tubing Engineer Signature ' Phone: 265 -1102 Date 3 /J6/ itigir RBDMS MAR 17 2010 c'L. -r'/ 7/6 3 ,4„ Form 10 -404 Revised 7/2009 Submit Original Only 1 ConocoPhillips Alaska, Inc. Drilling & Wells ConocoPhillips Coiled Tubing Drilling Alaska 3I -11L1 Completion Sundry 10 -404 Engineer: James Ohlinger Drilling Permit: 209 -1210 CT Drilling Engineer (907) 265-1102 Background /Status: CTD operations were conducted on the 3I -11 CTD sidetrack from 1/21/10 to 2/14/10. A window was milled in the 7" casing and the 3I -11L1 lateral was successfully drilled to a TD of 9437' MD. Drift problems were encountered while running the liner, and in addressing this problem, access to the 3I -11L1 lateral was lost. Operations were suspended on 2/13/10. Post -rig diagnostics have indicated the whipstock released and was pushed down hole. Well 3I -11 was opened to flow to tanks at 0945 hours on 3/3/10, and initially tested at —850 BLPD at 62.4% WC, 21.5 API, 0.75% solids at 950 WHP. The well was brought online to bring the reservoir pressure down before we potentially go back. The completion schematic is attached and shows 1182' of open hole between the window and top of liner before the whipstock fell losing the window. Plan Forward: The plan forward is to produce the well maintaining high WHP to protect the open lateral from wellbore sloughing. If production rates start to decline, lowering of the WHP will be considered. A re -drill of the original proposed targets is being considered in the May /June time frame. The redrill scope of work follows: Re -drill Scope: 1. MIRU Nabors CDR2 -AC rig using 2" coil tubing. NU 7 -1/16" BOPE, test. 2. 31 -11L1 Lateral (A2 Sand) a. Mill 2.80" 2- string window with high -side orientation at 6398' MD b. Drill 2.70" x 3" bi- center lateral in the A2 sand c. Load well with kill weight fluid. Run 2%" slotted liner with an aluminum liner -top billet 3. 3I-11L1-01 Lateral (A 1 Sand) a. Kick off of the aluminum billet b. Drill 2.70" x 3" bi- center lateral in the Al sand c. Load well with kill weight fluid. Run 2%" slotted liner with an aluminum liner -top billet 4. 3I-11L1-02 Lateral (A3 Sand) a. Kick off of the aluminum billet b. Drill 2.70" x 3" bi- center lateral in the A3 sand c. Load well with kill weight fluid. Run 2%" slotted liner from TD up to 6385' MD, into the 31/4" tubing 5. Freeze protect. ND BOPE. RDMO Nabors CRD2 -AC. 3/15/2010 3I -11L1 Completion 10 -404 Page 1 of 1 31 -11 Suspended CTD Sidetrack - Status as of - Up dated: 17- Feb -10 Camco TRMAXX -5E SSSV © 2212 MD (2.813" min ID, X- profile) _ 3 -1/2 ", 9.3# L -80 EUE 8rd -Mod Tubing to surface 16" 62# H -40 shoe @ 116' MD . 3 -1/2" Camco MMG gas lift mandrels (5) @ ® 2512', 3702', 4760', 5668', & 6074' 9 -5/8" 36# J -55 shoe @ 3383' MD IIIII III . X' landing nipple @ 6123' MD (2.813" min ID) • - Baker 3 -1/2" seal assembly 6131' - 6143' MD 1 1 80 -40 PBR at 6132' - 6145' I.. I Baker KBH Anchor Seal Assy at 6145' MD Baker SAB 40 -32 packer @ 6146' MD -g 'X' landing nipple @ 6156' MD (2.813" min ID) ;-;: ; Holes shot in 3 -1/2" straddle at -6408' -6413' & 6213' MD "i,J;i al �}a yy s - Baker F1 permanent packer @ 6422' MD (e -line set) ' w; 80 -40 Sealbore extension (6425'-6430') %1c 3 -1/2" straddle ; ;� D' landing nipple @ 6433' MD (2.750" min ID) cemented in place -" :`'r� WLEG @ 6438' MD FISH: 3 -1/2" monobore �a�' whipstock at 6422' (TOWS) J ®' Open hole: 6419' - 7590' MD J -__ ________ : __ _ -___ ___ _ _ 1 L1 TD @ 9437' (A2 A sand.perfs sand) A3: 6437' - 6454' A2: 6457' - 6486' Top of 2 -3/8" slotted Al: 6494' - 6503' FISH: 3 -1/2" monobore liner - 7590' whipstock E I I Depth unknown 7" 26# J -55 shoe @ 6550' MD .. G K UP 31 -11 L1 r. oi. ConocoP 1ithps ; ' Well Attributes Max Angle & MD I_TD , v4` / '' Wellbore APUUWI Field Name Well Status I Inc! (°) MD (ftKB) 1Act Btm (ftKB) Comment P (pp 6/22/2009 :Annotation Annt W a te /2 102 24 Grd (ft) 9lea Date _ 500292193260 KUPARUK FI 'tR UNIT PROD Comment 5125 {ppml Date A notationEnd Date KB - Grd (H) Rig Release "' 009 35 91 4/4/1989 —._ Well Config Schematic L 2 Ac/oal 5 :04 i 'NI - , Annotation Depth (HKB) End U 1 d Da Srnem tc�ACUaI [End b Last Tag' SLM 6,510.0 1/14 '10 I Annotation Last Mod ... En Rev Reason: CTD LATERAL, GLV C/0 Imosbor 2/22/2010 Casing Strings HANGER, 31 - Casing Description String 0 _ String ID .. Top (ftKB) Set Depth (L. Set Depth (TVD) String WI . String ... String Top Thrd 10P EN HOLE 4 6,409.0 7,591.5 6,226 0 ,Casing Description String 0 Slr in g ID . Top (ftKB) Set Depth (C.. Set Depth (TVD) String Wt. String ... String Top Thrd L1 LINLK - 'I -, 7,591.5 9438.0 4 /0 L -80 STL I. 14,..„: .,. ., .„. Liner Details ,� Top Depth (TVD) Top Inc] Nomi... Top (ftKB) (5168) ( °) Item D I.tion Comment -.. - -. -.. ID (in) 7,69L5 6,226.0 81.71 DEP. 111' 12.625" Baker deployment sleeve 1.000 Notes: General & Safety End Date Annotat 6/10/2009 NOTE. VIEW SCI1EIvIA IIC w /Alaska SchemaLC9.0 CONDUCTOR, 't, 2 /13!2010 NOTE. L1 has open hole in upper 1082', couldn't set upper liner: L1 -01 & L1 -02 not drilled 36- 116 - - - -- -- SAFETY VLV, 2,212 It GAS LIFT,_ - -. 2,512 ■ SURFACE,__ 35 -3,383 GAS LIFT, 3,702 W 1 ,. GAS LIFT, Illt 4,760 GAS LIFT, 5,668 C ii GAS LIFT, 6.074 NIPPLE, 6,123 -. II SEAL ASSV, 6,131 PBR, 6,132 1 L 7 SEAL ASSY, 6,145 PACKER, 6,146 Mandrel Details fl NIPPLE, 6,156 Top Depth Top Port Alf (TVD) Intl OD Valve Latch Size TRO Run Stn Topj(tKBL (ftKB) (°I Make Model (in) Sery Type Type (in) (psi) Run Date Com... WHIPSTOCK, - -.. _. 6,408 z. ,x 1 2 ,511.6 2,511 6 0.09 Ca ncc PING 1 1f2 GAS LIFT GLV R - 20 0.188 1,291.0 2/18/2010 CEMENT S02, 1 2 3 ,702.1 3,701.9 3.84 Camco MIMG 1 1/2 GAS LIFT GLV R - 20 0.188 1,280.0 2/18/2010 6,213 .. - - _ PRODUCTION. 33 -6,761 - ` . 3 4,706.8 23.38 Camco 1,1MG 1 1/2 GAS LIFT GLV R -20 0.188 1,287.0 2/18/2010 4 5,667.8 5,538.4 23.61 Camco MMG 11/2 GAS LIFT GLV IR -20 0.188 1,25502/18/2010 OPEN HOLE, ." 6409 - 7592 5 6,074.0 5,910.7 23.36 Camco IV/MG 1 1/2 GAS LIFT OV RDO 0.250 0.0 2/18/2010 TD (31-1111), 7 - - 9,4,4 37 11 LINER, 7,592 -9,438 DATE SUMMARY 31 -11 Pre and Post Rig Summary 12/5/09 DRIFTED TBG WITH 10' x 2.5 "; TAG @ 6500' RKB. SET 2.75" CA -2 PLUG @ 6433' RKB. SET CATCHER @ 6433' RKB. PULLED GLV @ 5667' RKB. IN PROGRESS. 12/6/09 PULLED GLVs @ 6074', 4760', 3702', 2511' RKB. SET DVs @ 5667', 4760', 3702', 2511' RKB. IN PROGRESS. 12/7/09 CIRCULATED 170 BBL DSL DOWN TBG TO IA. SET DV @ 6072' RKB. ATTEMPTED MIT IA, FAILED. ATTEMPTED PULL DV @ 6074' RKB. IN PROGRESS. 12/8/09 PULLED & REPLACED DV @ 6074' RKB. MIT IA 3000 PSI, GOOD. ATTEMPTED PULL CATCHER @ 6424' SLM, S/D HIGH @ 6415' SLM, POSSIBLE SCALE. IN PROGRESS. 12/9/09 BAILED SCALE FROM 6399' SLM TO 6426' SLM. IN PROGRESS. 12/10/09 BAILED SCALE OFF CATCHER SUB @ 6423' SLM, PULLED SAME. PULLED 2.75" CA -2 PLUG @ 6433' RKB. READY FOR E /L. 12/12/09 E -line set 3.5" HES Fastdrill Plug @ 6417' (top) +- 2 feet above packer at 6419'. return in the am to perforate tubing above plug. Utilized LRS to pressure test plug to 3000# (good)., in progress 12/13/09 PERFORATED 6408' -6413' AND 6208' -6213' WITH 2" MILLENNIUM HMX BH CHARGES, 6 SPF, 60 DEG PHASING.READY FOR COIL 12/19/09 PUMPED 10 BBLS 15.8 CLASS -G CEMENT FROM 6410 CORRECTED CTMD, JETTED TUBING TO TARGET TOC AT 6213 CTMD WITH BIOZAN AND S/W. WELL IS FREEZE PROTECTED TO 3000 FT. 12/21/09 TAG TOP OF CEMENT PLUG @ 6202' SLM. JOB COMPLETE 12/24/09 (PRE CTD) PT & DD TEST SSV, MV, SV - PASSED. DD TEST SSSV - FAILED. 12/30/09 PERFORM WEEKLY BOP TEST. MILL CEMENT FROM 6196' CTMD TO COMPOSITE BRIDGE PLUG @ 6424' CTMD. MILL PLUG & PUSH PLUG TO BTM @ 6500' CTMD. CHASE OUT W/ LARGE PILL OF BIOZAN. WELL FREEZE PROTECTED WITH DIESEL TO 5000' CTMD. WELL READY FOR SLICKLINE. 1/3/10 DRIFT TBG 2.67" & TAGGED @ 6502' SLM. DRIFT TBG 2.65" X 19.8' BOT DUMMY WHIPSTOCK TO 6502' SLM. LOG CALIPER f/ 6500' - 6089' SLM, DATA GOOD. COMPLETE. 1/4/10 DDT SSSV ( FAILED ) 1/4/10 BRUSH AND FLUSH TRMAXX -5E @ 2212' RKB. OBTAINED GOOD CLOSURE TEST. COMPLETE 1/14/10 TAG @ 6510' SLM. PERFORMED 30 MIN SBHP @ 6470' RKB =4099 PSI, 161 Deg F. 15 min GRADIENT @ 6361' RKB =4055 PSI. COMPLETE. 1/15/10 SQUEEZED 37 OF THE 42 BBLS OF 10 PPG VISCOSIFIED FLO -PRO INTO THE A SAND PERFS. DISPLACED WITH 36 BBLS OF SEAWATER AND 20 BBLS OF DIESEL FREEZE PROTECT. JOB COMPLETE. 1/26/10 FISHING ON CDR 2: ATTEMPTED FISH STUCK WHIPSTOCK. CLIPPED WIRE ON TRMAXX @ 2212' RKB (NOT LOCKED OPEN), LEAVING 31' OAL TOOLSTRING IN HOLE. IN PROGRESS. 1/27/10 FISHING ON CDR 2: RECOVERED LOST TOOLSTRING & WHIP STOCK PULLING TOOL. ATTEMPTED PULL WHIPSTOCK, NO SUCCESS. IN PROGRESS. 1/27/10 ATTEMPTED FISH WHIPSTOCK © 6107' SLM. UNABLE TO FULLY LATCH INTO RETRIEVING PROFILE TO ENABLE JARRING. TURNED BACK OVER TO CDR RIG TO FISH. 2/16/10 DRIFT TBG W/ 2.5" CENT -3' STEM- 3" BLB- 2.25" 3 PRONG WIRE GRAB (112" OAL) TO 6404' SLM, EST. 6424' RKB, APPROX 6' BELOW BTM OF CTD WINDOW @ 6418' RKB, NO PROBLEMS, NO RECOVERY OF LOST LEAD. PERFORM 30 MIN SBHP © 6400' RKB =4150 PSI, 152 DEG F. 15 MIN GRADIENT @ 6293' RKB =4100 PSI. IN PROGRESS. 2/17/10 RAN CALIPER SURVEY FROM 6424' TO 6320' CTMD. SET 3" SLIP STOP CATCHER @ 6074' SLM. IN PROGRESS. 2/18/10 PULLED DMY VLV's @ 2511',3702',4760',5668' & 6074' RKB's. INSTALLED NEW GLV DESIGN (REFRENCE PROCEDURE). DREW IA PRESSURE FROM 1600 # » » >300 #. PULLED CATCHER SUB @ 6074' SLM. JOB COMPLETE. . S Con ©coPhillips Time Log & Summary Wellview Web Reporting Report Well Name: 31 -11 Rig Name: NABORS CDR2 -AC Job Type: DRILLING SIDETRACK Rig Accept: 1/22/2010 2:00:00 PM Rig Release: 2/14/2010 12:00:00 PM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01/21/2010 24 hr Summary MOB CDR -2 TO31 -11 11:00 00:00 13.00 0 0 MIRU MOVE MOB P Rig on Rig Move 01/22/2010 Arrive on 31 @ 02:00, Spot on well 11. Rig up unit, Complete reel swap Prep for BOPE Test 00:00 14:00 14.00 0 0 MIRU MOVE MOB P Move in & spot equipment on 31 -11. replaced the skate rams on Injector. 14:00 18:00 4.00 0 0 MIRU WHDBO CTOP P Rig Accpet @ 14:00 hrs - Begin rigging up Iron in CT reel manifold. 18:00 23:00 5.00 0 0 MIRU WHDBO CTOP P Crew Change out. Working on Pressure Bulkhead, Greaseing valves, and ckokes, secure stack, bring on fluid in pits 23:00 00:00 1.00 0 0 MIRU WHDBO CTOP P PJSM, Install stuffing box, replace 0 -rings on lubricator 01/23/2010 Complete BOPE Test, Stab Coil, Perform slack mgmt. 00:00 02:00 2.00 0 0 MIRU WHDBO CTOP P Complete installing stuffing box 02:00 03:30 1.50 0 0 MIRU WHDBO CTOP P PJSM, Install BPV Lubricator, Shell test BOPE to 4000PSI, Pull BPV, Rig down Lubricator 03:30 12:30 9.00 0 0 MIRU WHDBO BOPE P Start BOPE Test. Low 250 High 4500psi. One valve veiled C -5. Replaced & tested. 12:30 13:30 1.00 0 0 MIRU WHDBO SFTY P Hold pre -spud meeting with conference call to town. Discussion the improtance of the window /whipstock setting and exit along with SSSV & KWF. 13:30 18:00 4.50 0 0 SURPRI WELLPF CTOP P Start stabbing CT 18:00 21:00 3.00 0 0 SURPRI WELLPF CTOP P Crew Change 21:00 21:30 0.50 0 0 SURPRI WELLPF CTOP P Pipe in chains, R/D grapple and cables 21:30 22:30 1.00 0 0 SURPRI WELLPF SFTY P Hold pre -spud meeting with conference call to town. Discussion the improtance of the window /whipstock setting and exit along with SSSV & KWF with night crew. PJSM to fill coil and slack mgmt. 22:30 23:45 1.25 0 0 SURPRI WELLPFCTOP P Replace Packoffs, line up and fill coil with seawater 23:45 00:00 0.25 0 0 SURPRI WELLPF SLPC P Unstab coil, ensure E -Line is up in coil. Stab back on and line up to reverse circulte Page 1 of 25 I Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01/24/2010 24 hr Summary Perform Slack Mgmt, Head up Coil Track, Dummy whipstock run, swap well to 9.3 milling fluid. Run Whipstock 00:00 00:45 0.75 0 0 SURPRI WELLPF SLPC P Reverse circulate coil, Surge 3 times, Unstab, Cut 25 feet coil and found e-line 00:45 01:30 0.75 0 0 SURPRI WELLPF SLPC P Test wire, all good, Prep coil and install connector, Pull test to 25K >550 Meg Ohms, 60 Ohms continuity 01:30 02:00 0.50 0 0 SURPRI WELLPF SLPC P M/U Upper Quick Connect, Pressure test to 4500 PSI, Good test. Bleed off 02:00 03:00 1.00 0 0 SURPRI WELLPF BOPE P R/U test pump and pressure test inner reel valve 03:00 05:15 2.25 0 0 PROD1 RPEQP1 PULD P PJSM, M/U and pressure deploy dummy whipstock, Surface test tool 05:15 06:15 1.00 0 1,000 PROD1 RPEQP1TRIP P RIH 06:15 06:45 0.50 1,000 1,000 PROD1 RPEQP1TRIP P Stop 1000' in well. Micro motions not working. Stop & re -set, check IA/OA gauges and ensure SSSV is pumped open. Finish setting up equipment & guages at surface. WHP 1200 psi. IA - 830 / OA 11. Fix controls on Managed pressure choke. 06:45 08:15 1.50 6,000 6,000 PROD1 RPEQP1TRIP P RIH - perfrom P/U weight check & pipe inspection. Follow MP schedule circ. seawater in hole taking returns to tiger tank, pumping 1 bpm. Weight check @ 5000 ft - 18K, looked good. 08:15 09:15 1.00 6,300 6,400 PROD1 RPEQP1 DLOG P Tie in to formation @ 6245'. Circulate SW B /U. +12 ft. - 6320' stop and switch to CCL log. Log down to 6500'. Collars are 1.77' higher. 09:15 10:45 1.50 6,400 6,400 PROD1 RPEQP1OWFF P P/U & perform static test with SW @ 6400'. Trapped 1200psi on WH. BHP - 4009 psi. WH pressure built up to 1330 in 5 minutes. Stabilized. BHP 4066psi, ECD 12.84. Circ out sea water with 9.3#. 10:45 12:15 1.50 6,400 71 PROD1 RPEQP1TRIP P POOH following MP BHP pumping 9.3# flo -pro. 12:15 12:45 0.50 71 71 PROD1 RPEQP1OWFF P CT @ surface 1000psi @ surface. Shut in SSSV to see if it will hold. Bled off WH & Circ pressure. Still getting slight flow over teh shakers. Shut in choke and the WHP built up to 1000 psi in 5 minutes. SSSV NOT HOLDING. 12:45 14:45 2.00 0 0 PROD1 RPEQP1 PULD P Undeploy BHA - Tighten reel bolts after rolling on bottom. Swap BHA from pipe shed. 14:45 15:45 1.00 0 70 PROD1 RPEQPI PULD P Deploy BHA #2 - whipstock assembly. 15:45 18:00 2.25 70 4,400 PROD1 RPEQP1TRIP P RIH 60fpm, EDC open pumping .3 bpm. Page 2 of 25 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 19:00 1.00 4,400 5,100 PROD1 RPEQP1TRIP P Crew change, Hydraulic hose failure on injector cart, repair hose. Return fluid weight down to 9 PPG with lel indication. Ship gassy returns to tiger tank. Increase choke pressure 100 PSI 19:00 19:45 0.75 5,100 6,255 PROD1 RPEQP1 DLOG P 6255 start Gamma Ray Tie In +7 foot correction RIH to set Whipstock 19:45 20:00 0.25 6,255 6,408 PROD1 RPEQP1WPST P Set @ 6408 bit. 8.7' high. Call town. Set up to retrieve whipstock 20:00 21:00 1.00 6,350 6,350 PROD1 RPEQP1CIRC T Circulate bottoms up. Getting low mud weight back with gas burps. BHP =4080 21:00 22:15 1.25 6,350 70 PROD1 RPEQP1TRIP T Trip out of well following pressure schedule 22:15 23:30 1.25 70 0 PROD1 RPEQP1PULD T Undeploy BHA #2, Lay down whipstock setting tools 23:30 00:00 0.50 0 PROD1 RPEQP1 PULD T Configure BHA 01/25/2010 Latch whipstock, Overpull @ 6135 and left fish, rerun hook unable to latch. Run LIB to determine orientation 00:00 00:45 0.75 0 0 PROD1 RPEQP1 PULD T M/U whipstock retrival tool. Scribe to Coil Track 00:45 01:45 1.00 0 0 PROD1 RPEQP1 PULD T Pressure Deploy, M/U injector to BHA and surface test 01:45 03:30 1.75 0 6,235 PROD1 RPEQP1TRIP T Open EDC before opening deployment rams, RIH following pressure schedule 03:30 03:45 0.25 6,235 6,284 PROD1 RPEQP1 DLOG T 6235, Tie In Pass, 4 FPM, Correct +7, Shut EDC 03:45 04:00 0.25 6,284 6,403 PROD1 RPEQP1 TRIP T Trip in hole to retrieve whipstock, PUW =21K @6350, RIW =13K 04:00 04:30 0.50 6,403 6,140 PROD1 RPEQP1 FISH T 6402 Set down Picked up saw -4.2k direct pull then came free. PUH to 6388, RBIH ran clear to 6406 with no bobble or setdown 04:30 04:45 0.25 6,140 6,140 PROD1 RPEQP1 FISH T 6140' overpull 4200 Lbs, Nothing in this area, seems to indicate we have whipstock. 04:45 07:45 3.00 6,140 63 PROD1 RPEQP1TRIP T POOH 50 fpm- no more weight bobbles to surface. Did not see SSSV while pulling through. Treat undeployment as BHA is on fish. 07:45 09:15 1.50 63 0 PROD1 RPEQP1PULD T Safety meeting & undeploy BHA. Fish not recovered. 09:15 10:15 1.00 0 0 PROD1 RPEQP1CTOP T Inspect choke Bat surface. Pressure spikes on MP choke while RIH /POOH. Call town to discuss next run(s). 10:15 11:15 1.00 0 63 PROD1 RPEQP1 PULD T Deploy Fishing BHA. 11:15 13:15 2.00 63 5,600 PROD1 RPEQP1TRIP T RIH - Stop @ 4000 ft to fix digital parameters on MP choke. Did not let BHP drop below 3000 psi while functioning at surface. Continue RIH, watch for influx. Page 3 of 25 I Ti me Logs Date From To Dur S. Depth E. Depth Phase - Code Subcode T Comment 13:15 16:45 3.50 5,600 6,135 PROD1 RPEQPI FISH T Weight check 5600' - P/U 15K, Orientate BHA to 280 degrees. No fish at 5668' Continue to RIH. Light gas cut mud / divert to U. 9.16# mud. RIH tagged up @ 6135', sat down 3.4K. P/U weight 19K, 16:45 18:45 2.00 6,135 6,135 PROD1 RPEQP1 FISH T Finally sat down weight higher after 30 attempts. Normal sit down depth 6143.5' Sat down @ 6131.5' to 5K 130R. P/U weights 20K at surface, set down weight 9K @ surface. Lower slot may be @ 6133'. No luck Keep fishing and turning. 18:45 20:45 2.00 6,135 6,135 PROD1 RPEQPI FISH T Crew change, make a couple of try tags then set up to pump. Start pumping 1.3 bpm, Circ. press 3500psi, WHP 750, BHP 4060psi. No luck after numerous tries at all toolfaces. 20:45 21:45 1.00 68 68 PROD1 RPEQP1TRIP T POOH for LIB run. 21:45 22:45 1.00 68 0 PROD1 RPEQP1PULD T CT @ surface - Undeploy. 22:45 23:45 1.00 54 54 PROD1 RPEQP1 PULD T P/U BHA # 5 with 2.74" LIB 23:45 00:00 0.25 54 54 PROD1 RPEQP1TRIP T RIH @ Midnight 01/26/2010 Continue fishing operations. LIB run show, attempt to engage a drive down tool and push whipstock down with no success, unble to cock jars. RU Slickline unit. 00:00 01:30 1.50 54 6,080 PROD1 RPEQP1TRIP T Trip in Hole with LIB, BHA #5 01:30 02:00 0.50 6,080 6,120 PROD1 RPEQPI DLOG T Tie into formation, poor correlation made no correction PUH to 6100 Depth correction was -20 but not made due to all last corrections +7 to +12. If we had made correction puts fish @ 6133' right were its supposed to be 02:00 03:00 1.00 6,120 6,153 PROD1 RPEQP1TRIP T RIH @ 10 FPM tag @ 6153 uncorrected, POOH following pressure schedule 03:00 04:30 1.50 6,153 0 PROD1 RPEQP1PULD T At Surface, PJSM, Undeploy BHA # 5, LIB 04:30 06:30 2.00 0 0 PROD1 RPEQP1OTHR T Call town and discuss options. Review whipstock and jar down sub and slip relationship with BOT and BHI 06:30 08:00 1.50 0 0 PROD1 RPEQP1PULD T M/U BHA#6 Jar down Sub, Pressure deploy, Surface test 08:00 10:30 2.50 0 6,000 PROD1 RPEQP1TRIP T Trip in well 10:30 11:00 0.50 6,000 6,100 PROD1 RPEQPI DLOG T Perform CCL Log, +9 foot correction, PUH and perform Gamma Tie in -2 foot correction RIH to fish 11:00 15:00 4.00 6,133 6,137 PROD1 RPEQP1FISH T Tag pinch point, Attempt to latch fish. Multiple orientations and speeds 15:00 17:00 2.00 6,133 6,137 PROD1 RPEQP1 FISH T Continue to try & latch fish. Page 4 of 25 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:00 17:15 0.25 6,130 6,137 PROD1 RPEQP1 FISH T Made several Attempt to re -set jar's. Unable to get enough rate to re -set jars due tubing psi. 17:15 18:30 1.25 6,137 6,137 PROD1 RPEQP1 FISH T Discuss opitions with Town Engineer & Well Group supervisor on getting slick -line unit & crew. 18:30 20:00 1.50 6,137 0 PROD1 RPEQP1TRIP T POOH, SL arrived on location. TGSM and spot up unit 20:00 21:30 1.50 0 0 PROD1 RPEQP1PULD T Undeploy BHA 21:30 22:00 0.50 0 0 PROD1 RPEQP1 SFTY T PJSM with HES SL crew and rig crew 22:00 00:00 2.00 0 0 PROD1 RPEQP1 SLKL T RU SL equipment, MU SL BHA with LIB. PT SL lubricator to 3000 psi 01/27/2010 Fishing with Slickline 00:00 01:30 1.50 0 0 PROD1 RPEQP1SLKL T Run LIB on SL. LIB shows the top of • the WS is still in good shape, sitting about 1/2" to 9/16" from tubing wall, oriented with the face to the low side. This indicates that at some point the the orienter rotated the WS. (2.758 LIB) 01:30 03:00 1.50 0 0 PROD1 RPEQP1SLKL T Set up shrouded hook on decentralizerto engage WS oriented to the low low side (hook pointed up) 03:00 04:24 1.40 0 0 PROD1 RPEQP1 SLKL T RIH with SL, tagged fish and able to get a friction bite up to 1400 #. pops free when spanging up. POOH for more lubricator, stem and oil jars. 04:24 05:00 0.60 0 0 PROD1 RPEQP1 SLKL T lost tool string at SSSV. Had 3300 psi on it. 05:00 06:00 1.00 0 0 PROD1 RPEQP1SLKL T Ooh with parted slick -line. HES day crew change out with night crew. PJSM with rig crew and HES crew and discuss plan forward with all 06:00 07:15 1.25 0 6,138 PROD1 RPEQP1SLKL T Rlh with slick -line pulling tool to locate and pull lost tool string. 07:15 08:45 1.50 6,138 0 PROD1 RPEQP1 SLKL T OOH with SL fishing tool and lost string. PJSM / bleed down and remove fish. 08:45 10:15 1.50 0 0 PROD1 RPEQP1SLKL T Swap toolstring.Discuss next plan forward 10:15 13:00 2.75 0 0 PROD1 RPEQP1SLKL T Start making up new fishing bha.(RS,QC, 5'x2.125" WB,QC,KJ,S'x2.125" WB,QC,OJS,QC,KJ,LSS,QC. 13:00 13:30 0.50 0 0 PROD1 RPEQP1SLKL T Stab on well.pt equip.Rih w /3" GR, 2.31" bait sub, kj & whipstock pulling tool. 13:30 14:15 0.75 0 6,135 PROD1 RPEQP1SLKL T SD @ 6135 slm on whipstop. Beat do for 25 min, able to pull 1100# bind & then come free. Repeat 2 times, No success, pooh w/ pulling tools. 14:15 15:00 0.75 6,135 0 PROD1 RPEQP1SLKL T OOH.bleed down and remove fishing. Discuss plan forward. Prep for another LIB run. Page 5 of 25 . 0 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T ' Comment 15:00 16:30 1.50 0 6,135 PROD1 RPEQP1SLKL T Rih w /KJ 2.75" decentrilizer and 2.75" LIB. After pooh. Block shows whip stock @ 6:00 on low side faceing up. 16:30 18:30 2.00 6,135 0 PROD1 RPEQP1SLKL T Start working on BHA for next fishing attempt. 18:30 20:30 2.00 0 0 PROD1 RPEQP1SLKL T RIH with unshrouded hook, decentralizer set for hook pointed to low side. Could not get hooked in. POOH 20:30 22:06 1.60 0 0 PROD1 RPEQP1SLKL P Examined hook and decided to orient to 90 right based on marks on retrieval hook. RIH and after repeated attempts to spang down, hooked into WS, three oil jar licks and 10 spang licks before shearing brass pin in GR. POOH 22:06 00:00 1.90 0 0 PROD1 RPEQP1 SLKL T RIH with steel pinned GR and got about 15 oil jar licks and 30+ sprangs before shearing. POOH 01/28/2010 Fishing with Slickline. No success with SL, Continue fishing operations with CT 00:00 00:45 0.75 0 0 PROD1 RPEQPI SLKL T Continue fishing operations with SL. Have a baited hook in the WS. RIH with GS to resume up jars on fish. engaged baitsub and disengged hook. Tried to re -hook WS with no success. POOH 00:45 01:45 1.00 0 0 PROD1 RPEQP1 SLKL T Cut some wire, check stuffing box and RIH with baited hook, GR and same orientation on decentralizer. Unble to hook WS. POOH 01:45 04:15 2.50 0 0 PROD1 RPEQP1SLKL T Check tool for indication of WS face and re- orient hook. RIH w/ double knuckle and 3" GR w/2.72" bait sub,decent,clock d -pin sub and whipstock hook @ 09:00. Sat down @ 6107' slm. lightly tap down, pull friction bite, and pull free. Sat down. beat down several times and same result. Make 3 more attempts & POOH. 04:15 04:45 0.50 0 0 PROD1 RPEQP1SLKL T OOH. Bleed down. Marks indicated hook needs to be rotated 45 degress. 04:45 06:15 1.50 0 0 PROD1 RPEQP1 SLKL T Make adjustment to tool and rih. Sat down @ 6107' slm and obtain small friction again. Continue to work tools w /same result. POOH 06:15 07:00 0.75 0 0 PROD1 RPEQP1SLKL T OOH.Make Changeout. 07:00 09:45 2.75 0 0 PROD1 RPEQP1SLKL T Orientate 90 deg.stab on pt.Rih w/ same to 6111' slm seen 400# overpull let jars fire.Slip off beat down. Same results 2 more times. POOH. Page 6 of 25 • . Time Logs Date From To ` Dur S. Depth ` E. Depth Phase Code Subcode T `' Comment 09:45 10:30 0.75 0 0 PROD1 RPEQP1SLKL T OOH, Bleed down and remove tools. While removing tools had a large chunk of rubber fall from inside lubricator. Discuss with all about rubber piece. Rubber may have come from FAS Drill Bridge Plug from 12/30 milling operation with service coil? 10:30 12:00 1.50 0 0 PROD1 RPEQP1SLKL T Stab on well again with same. Rlh for another attemp to hook whipstock.SD @ 6111' slm still not able to latch. 12:00 13:30 1.50 0 0 PROD1 RPEQP1SLKL T Rlh w /dbl kj,gr,b.s. and 2.75" LIB to sd @ 6106' slm.pooh 13 :30 16:00 2.50 0 0 PROD1 RPEQP1SLKL T Rlh w /DBL KJ,GR pulling tool, B >S> decent clock for whipstock pulling tools 12:00 Able to get small friction bites. Continue to work with same result. Crew change out.Work tool some more. Had small oil jar lick with a 1400 lb bind.Slackoff and hit slight lick and come free again. POOH 16:00 16:30 0.50 0 0 PROD1 RPEQP1SLKL T OOH.Bleed down and inspect hook. Still indication that tool is not entering into profile to get a latched. 16:30 19:00 2.50 0 0 PROD1 RPEQP1SLKL T Adjust orientation and RIH. Unable to hook WS. POOH 19:00 21:15 2.25 0 0 PROD1 RPEQP1SLKL T RD SL and release LRS 21:15 21:30 0.25 0 0 PROD1 RPEQPI SFTY T PJSM for deployment of BHA #7 21:30 23:30 2.00 0 0 PROD1 RPEQPI PULD T Deploy BHA #7, Inteq tools and LIB 23:30 00:00 0.50 0 2,500 PROD1 RPEQPI TRIP T RIH following MPD tripping schedule 01/29/2010 Ran LIB on coil, attempted to fish whipstock, pushed whipstock to 6425' TOWS. Stand by for phase three weather for 10 hours. 00:00 01:00 1.00 2,500 6,025 PROD1 RPEQP1TRIP T Continue RIH 01:00 01:30 0.50 6,025 6,110 PROD1 RPEQP1DLOG T Log Gamma, -2' correction. Log CCL, this would be a plus 2' to get on the tubing tally depths. 01:30 01:45 0.25 6,110 6,138 PROD1 RPEQP1FISH T 9K RIW, 19K PUW while pumping 1 BPM and holding 700 WHP for 4000 DHP. Tag WS at 6137.7' (this would be - 6139.7' on the tubing tally) with 3K DHWOB, 6K surface weight. 01:45 02:45 1.00 6,138 0 PROD1 RPEQP1TRIP T POOH 02:45 04:15 1.50 0 0 PROD1 RPEQP1PULD T Undeploy BHA #7. LIB shows tray on low side. 04:15 05:30 1.25 0 0 PROD1 RPEQP1PULD T deploy BHA #8, retrieval hook and jars. Field went to phase 3 at 4:40 AM. Continue deploying BHA. Page 7 of 25 11 411 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:30 13:00 7.50 0 0 PROD1 RPEQP1OTHR T At surface with BHA #8, Field is in phase three conditions. Continue pumping down MPL at 1200 psi 13:00 14:45 1.75 0 6,000 PROD1 RPEQP1TRIP T Field went to phase two, RIH w /Spear 14:45 15:00 0.25 6,000 6,120 PROD1 RPEQPI DLOG T Slow speed down to 20 fpm for tie in _ W /CCL. 15:00 15:15 0.25 6,120 6,050 PROD1 RPEQPI DLOG T PUH W /CCL to continue with tie.Up wt= 18500# 15:15 15:30 0.25 6,050 6,092 PROD1 RPEQPI DLOG T Rih again @ 4 fpm w/ ccl. Correction is -4 . Re -set counter to 6088' ctmd. 15:30 15:45 0.25 6,092 6,141 PROD1 RPEQP1 FISH T Let tool orientate with hook pointed down (low side). Rih and attempt to latch.Rih wt =10k 15:45 16:00 0.25 6,141 6,429 PROD1 RPEQPI FISH T Tag top whipstock @ 6141' . Made several attempt to latch. Seen a couple of small overpull no luck latching. Rih for another attempt.Able to rih pushing whipstock. 16:00 16:30 0.50 6,429 6,429 PROD1 RPEQPI FISH T Sat down with whipstock @ 6429'. Continue to try and work whipstock passed tail pipe. 16:30 16:45 0.25 6,252 6,279 PROD1 RPEQPI TRIP T Unable to get whipstock out of tailpipe. Calling bottom of fish @6333 in D- Nipple. Engaged 3' into fish, TOF @ 6425 POOH - Perform tie into K1 on way out 16:45 18:45 2.00 6,279 0 PROD1 RPEQP1TRIP T Tie in resulted in no correction, Trip Out 18:45 21:15 2.50 0 0 PROD1 RPEQP1OTHR T Stand by for weather 21:15 21:30 0.25 0 0 PROD1 RPEQP1SFTY T Phase 2, PJSM for undeploying BHA 21:30 22:30 1.00 0 0 PROD1 RPEQP1 PULD T Undeploy fishing BHA, #8 22:30 23:30 1.00 0 0 PROD1 RPEQPI PULD T Deploy dummy whipstock BHA, #9 23:30 00:00 0.50 0 2,500 PROD1 RPEQP1TRIP T RIH 01/30/2010 Ran dummy whipstock to 6423'. Set whipstock at 6108' TOWS. RIH with first window milling assembly and started milling window 00:00 00:48 0.80 2,500 6,240 PROD1 RPEQP1TRIP T Continue RIH, no set downs or unusual weights observed while RIH. 00:48 01:00 0.20 6,250 6,300 PROD1 RPEQP1 DLOG T Tie in, -2' correction 01:00 01:06 0.10 6,300 6,423 PROD1 RPEQP1TRIP T Weight check, 20K PUW, 14K RIW. RIH to 6423'. No set downs. 01:06 02:18 1.20 6,423 0 PROD1 RPEQP1TRIP T POOH 02:18 03:18 1.00 0 0 PROD1 RPEQPI PULD T Undeploy BHA # 9, 03:18 03:36 0.30 0 0 PROD1 RPEQPI BOPE P Function test BOP 03:36 04:36 1.00 0 0 PROD1 RPEQPI PULD T Deploy BHA # 10, Whipstock deux 04:36 06:30 1.90 0 6,265 PROD1 RPEQP1TRIP T RIH at 60 FPM with EDC open and following MPD tripping schedule Page 8 of 25 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:30 06:45 0.25 6,265 6,293 PROD1 RPEQP1 DLOG T Start tie in log @ 4 fpm from 6250' to 6300' / rih wt =13K. Had -2 foot correction.Shut down pump.Close EDC and perform pick -up wt =18k. 06:45 06:51 0.10 6,293 6,417 PROD1 RPEQP1TRIP T RIH to whipstock set depth. 06:51 07:03 0.20 6,417 6,380 PROD1 RPEQP1WPST P On Depth with Whipstock @ 6416.76' ( Top of Whipstock 6408' and ) Set down 3K to confirmed Whipstock. Good set. Open EDC. PUH / On line pumping 10 ppg mill fluid. Up Wt =21 K 07:03 09:00 1.96 6,380 0 PROD1 RPEQP1TRIP P 6380 - Circulate well to 10 PPG Milling fluid.POOH 09:00 09:30 0.50 0 0 PROD1 RPEQP1 SFTY P OOH.Close EDC / PJSM. Discuss Un- Deploy process. 09:30 11:30 2.00 0 0 PROD1 WHPST PULD P Start Un- Deploy of BHA #10. 11:30 12:00 0.50 0 0 PROD1 WHPST PULD P Done removing BHA #10. PJSM Before making up BHA #11 12:00 12:15 0.25 0 0 PROD1 WHPST PULD P Crew Change Out. PJSM. Continue w/ BHA #11 12:15 12:45 0.50 0 0 PROD1 WHPST PULD P Start PSI De -Ploy Operations BHA #11 Mill 2.74 NoGo String Reamer 2.74 Go, 2.73 NoGo 12:45 13:30 0.75 0 0 PROD1 WHPST PULD P Make up Coil To BHA., Surface test tool, Strip down. Line up valves to RIH 13:30 14:30 1.00 0 6,255 PROD1 WHPST TRIP P RIH 14:30 14:35 0.09 6,255 6,275 PROD1 WHPST DLOG P Slow down to 2 fpm to log w /GR for tie end. rih wt= 13k.Stop logging@ 6277. -2 foot correction.change depth from 6277' to 6275' Up wt=21k 14:35 14:59 0.40 6,275 6,410 PROD1 WHPST TRIP P Continue to rih w /pumps offline to tag TOWS.RIH wt= 12500# .ctp= 1250psi / whp= 885psi. Tag TOWS @ 6409.83. PUH 10' up wt =20K. 14:59 15:14 0.25 6,395 6,409 PROD1 WHPST MILL P On line w /pump @ 1.6 bpm / ctp =4325 / whp =455 / rih wt =11 k / ECD 13.19.Continue in hole to Establish a milling pattern.Seeing a little motor @ 6409.35. 15:14 17:44 2.50 6,409 6,411 PROD1 WHPST MILL P Continue to time mill while establishing a pattern. ctp =4350 @ 1.60 bpm / whp =455 psi / 10.0 ppg milling fluid. 17:44 23:59 6.25 6,411 6,414 PROD1 WHPST MILL P Currently @ 6410.7' time milling. Continue at -0.5 FPH with 2 -2.5K WOB and 200 PSI motor work. 450 WHP to maintain 4175 DHP, 13.13 ECD 01/31/2010 Completed window milling operations. Page 9 of 25 I Time Logs Date From To bur S. Depth E. Depth Phase Code Subcode T Comment 00:00 03:33 3.55 6,414 6,415 PROD1 WHPST MILL P Currently @ 6414' time milling. Continue at <0.5 FPH with 1.7 -2.4K WOB and 200 PSI motor work. 450 WHP to maintain 4175 DHP, 13.13 ECD 03:33 04:16 0.72 6,415 6,415 PROD1 WHPST MILL P Ream window up and down at 1 FPM, three times. Dry tag at 6414.6. 04:16 06:00 1.74 6,415 0 PROD1 WHPST TRIP P POOH 06:00 10:00 4.00 0 0 PROD1 WHPST PULD P OOH. PJSM / Start UN- Deploy ! Deploy Process. 10:00 12:15 2.25 0 6,265 PROD1 WHPST TRIP P Trip in hole with fixed 2.5 degree fixed bent housing Weatherford motor with bit box turned down to 2.125 and 2.74 mill 12:15 12:45 0.50 6,265 6,293 PROD1 WHPST DLOG P Rih Wt =13K /ctp =1760 psi @ 0.30 bpm / whp =770 psi.Perform tie -in for correction to PDC gamma ray log @ 2 fpm. Wt Ck= 22500#. - 3' correction / change depth to 6290.46' feet. Orient tool face 15 deg.Close EDC. 12:45 13:45 1.00 6,293 6,415 PROD1 WHPST TRIP P Rih to 10' above TOWS and increse rate 1.4 bpm. RI H wt 12k ! ctp =4080 ! whp= 695psi 13:45 13:59 0.24 6,415 6,415 PROD1 WHPST MILL P Start milling operations @ 6414.6' MD 13:59 15:29 1.50 6,415 6,417 PROD1 WHPST MILL P Currently @ 6415.2 time milling. Continue at <0.5 FPH with 1.8 -2.5k WOB and 150 psi motor work. 500 WHP, 13.20 ECD. 15:29 16:29 1.00 6,417 6,418 PROD1 WHPST MILL P Seen good Mill -off @ 6416.5'md. Continue mill operation @ 1.0 FPH with 1 -1.5k WOB and 200 psi motor work. 500 WHP, 13.20 ECD.Get Sample from shaker.(cement & metal from shaker) 16:29 18:29 2.00 6,418 6,419 PROD1 WHPST MILL P Get another Sample from Shaker from 6417.3'md. Continue milling. 18:29 20:41 2.20 6,419 6,429 PROD1 WHPST MILL P Appear to be hanging up BHA at some point, unable to get motor work Stalled motor after getting more agressive with set down weight, 6319.75', WOB was 5.5K at stall. Continue milling formation at <5K WOB, 50 - 100 PSI motor work, 4 -10 FPH 20:41 21:41 1.00 6,429 6,400 PROD1 WHPST MILL P Back ream at +!- 45 deg. at 1 FPM, 2K over pulls at 6420' and 6417'. Drift with pump down two times, slight weight swings at 6419', 1 -2K WOB but able to drift to 6429'. 21:41 22:59 1.30 6,400 0 PROD1 WHPST TRIP P Open EDC and circulate in clean 10.0 PPG flo -pro and POOH Page 10 of 25 Time Logs Date From To bur S. Depth E. Depth Phase Code Subcode T Comment 22:59 23:59 1.00 0 0 PROD1 WHPST PULD P Undeploy BHA # 12. Mill came out 2.74" Go / 2.73" no -go. Pictures on S- drive. 02/01/2010 Drill The Build From 6429' to 6730'. Trip fo Lateral BHA. Start Drilling On Lateral. 00:00 02:00 2.00 0 0 PROD1 DRILL PULD P Deploy BHA # 13 for build section 02:00 03:30 1.50 0 6,250 PROD1 DRILL TRIP P RIH following MPD schedule 03:30 03:48 0.30 6,250 6,300 PROD1 DRILL DLOG P Tie in, -2' correction. Close EDC 03:48 04:00 0.20 6,300 6,430 PROD1 DRILL TRIP P RIH, tag at 6419', PU (20K PUW)and on second attempt saw some weight stacking but made it through. Start drilling at 6429.5' 04:00 06:00 2.00 6,430 6,500 PROD1 DRILL DRLG P Drilling ahead, 1.3 BPM, 4200 CTP, 490 WHP, 4200 DHP, 9K RIW, 1 -2K DHWOB, 100 -200 psi motor work, 40 -60 ROP 06:00 08:00 2.00 6,500 6,580 PROD1 DRILL DRLG P Crew change.DD Wiper @ 6500' md. Call for sample @ shaker. Continue drilling ahead 1.3 BPM, 4050 CTP, 420 WHP, 4200 DHP, 10K RIW, 1 -1.5K DHWOB, 100 -150 psi motor work, 30 to 50 ROP 08:00 08:30 0.50 6,580 6,430 PROD1 DRILL WPRT P Wiper Trip @ 6580'.UP Wt =20K CTP =4220 psi @ 1.33 bpm / whp =400 psi ECD @ 13.0. 08:30 09:00 0.50 6,430 6,580 PROD1 DRILL WPRT P Rlh from Wiper Trip back to last Drilling Depth. 09:00 12:15 3.25 6,580 6,730 PROD1 DRILL DRLG P Drilling ahead again @ 1.33 bpm / CTP =3980 psi / whp =398 psi / 4220 DHP, 10K RIH Wt, 1.5 - 2.0 DHWOB 175 - 200 psi motor work, 35 to 40 ROP 12:15 14:00 1.75 6,730 0 PROD1 DRILL TRIP P Done With Drill the Build, Start POOH following MPD schedule to PU Lateral BHA .Up wt =21 K / CTP =3780 @ 1.3 bpm / whp =400 psi / ECD @ 13.0 / 4180 DHP.Open EDC Above Window.Seen 5k overpull while pulling through window @ min rate. 14:00 15:15 1.25 0 0 PROD1 DRILL PULD P OOH.PJSM.Un- Deploy BHA #13 15:15 17:00 1.75 0 0 PROD1 DRILL PULD P Deploy BHA # 14 for Lateral L1 Horizontal Section. 17:00 18:15 1.25 0 6,265 PROD1 DRILL TRIP P RIH following MPD Schedule. 18:15 18:30 0.25 6,265 6,430 PROD1 DRILL DLOG P Tie in, @ 4 fpm / Rih Wt =14K -2' correction. Change depth from 6291.73 to 6289.73. Close EDC. 18:30 19:15 0.75 6,430 6,730 PROD1 DRILL DLOG P Start MAD -pass through build section.RIH Wt =15K Page 11 of 25 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:15 23:00 3.75 6,730 6,812 PROD1 DRILL DRLG P Drilling ahead, 1.3 BPM, 4025 CTP, 350 WHP, 4250 DHP, 10K RIW, 1.5 - 2.3K DHWOB, 150 - 200 psi motor work, 30 -40 ROP. ROP dropped off to 10 FPH with a short drilling break from -6775' to 6787'. 23:00 00:00 1.00 6,812 6,815 PROD1 DRILL DRLG P ROP <10 FPH most of the way with up to 3.4K WOB. PUH to try to clean bit, circ pressure is up by -30 psi. Cuttings show silt/clay's but no ankerite. Attempt to drill ahead with >1K WOB, no change. Increase pump rate to 1.5 BPM, 4300 CTP, 360 WHP, 4257 DHP. 02/02/2010 Tripped for bit, drilled lateral. 00:00 02:00 2.00 6,815 0 PROD1 DRILL TRIP P POOH due to lack of ROP, clean wiper to window, open EDC for tripping 02:00 03:15 1.25 0 0 PROD1 DRILL PULD P Undeploy BHA # 14 03:15 04:15 1.00 0 0 PROD1 DRILL PULD P PJSM Deploy BHA # 15 04:15 05:30 1.25 0 6,265 PROD1 DRILL TRIP P RIH W /BHA #15 1.05 degree motor and Hycalog Bi Center with razor cutters 05:30 05:45 0.25 6,265 6,284 PROD1 DRILL DLOG P Perform Gamma Tie In -4' Correction, Close EDC and RIH 05:45 06:00 0.25 6,284 6,814 PROD1 DRILL TRIP P Stack out on window 2X, @ 20FPM, Orient to 10R and run through, Tag @ 6814 06:00 08:15 2.25 6,814 6,965 PROD1 DRILL DRLG P 6614 Drill Ahead, 12.5K RIW 1.35 BPM @ 3950 FS BHP =4175, 40 -60 FPH ROP 08:15 09:00 0.75 6,965 6,965 PROD1 DRILL WPRT P Wiper trip to window PUW= 22500 1.33 BPM @ 3950 FS 09:00 09:15 0.25 6,965 6,981 PROD1 DRILL DRLG P 6965 Drill Ahead 1.34 @ 4000 FS BHP =4330 09:15 00:00 14.75 6,981 6,300 PROD1 DRILL OTHR T Field in Phase 3 PUH through window, open EDC and circulate 02/03/2010 Resume operations after Phase 3 Conditions, drilling L1 lateral from 6981' to 7746'. 00:00 04:30 4.50 6,390 6,390 PROD1 DRILL OTHR T Field in Phase 3. Circulating at .5 BPM, holding 590 WHP to maintain 4200 psi at the bit 04:30 04:54 0.40 6,390 6,981 PROD1 DRILL WPRT P Close EDC, 20K PUW, 13K RIW, tie in to RA, zero correction. Wiper to bottom was clean. 04:54 07:12 2.30 6,981 7,130 PROD1 DRILL DRLG P Drilling ahead, 1.3 BPM, 3900 CTP, 310 WHP, 4250 DHP, 10K RIW, 1- 2K DHWOB, 150 - 250 psi motor work, 60 -100 ROP. 07:12 08:00 0.80 7,130 7,130 PROD1 DRILL WPRT P Wiper trip to window, 20K PUW clean hole coming up. Wiper to bottom, 14K RIW, clean. Page 12 of 25 ! • Time Logs Date > From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:00 08:54 0.90 7,130 7,201 PROD1 DRILL DRLG P Drilling ahead, 1.3 BPM, 3900 CTP, 310 WHP, 4280 DHP, 10K RIW, 1- 2.5K DHWOB, 150 - 250 psi motor work, 60 -100 ROP. 08:54 09:24 0.50 7,201 7,201 PROD1 DRILL WPRT P Geo wiper up to 6800' 09:24 10:54 1.50 7,201 7,280 PROD1 DRILL DRLG P Drilling ahead, 1.3 BPM, 3900 CTP, 310 WHP, 4280 DHP, 10K RIW, 1- 2.5K DHWOB, 150 - 250 psi motor work, 60 -100 ROP. Need to level off now! 10:54 11:54 1.00 7,280 7,280 PROD1 DRILL WPRT P Wiper trip to window, 20K PUW, 13K RIW. Clean trip 11:54 13:06 1.20 7,280 7,430 PROD1 DRILL DRLG P Drilling ahead, 1.3 BPM, 3900 CTP, 315 WHP, 4260 DHP, 10K RIW, 1- 2.5K DHWOB, 150 - 250 psi motor work, 80 -150 ROP. 13:06 13:48 0.70 7,430 6,436 PROD1 DRILL WPRT P Wiper to window. 20K PUW 13:48 13:54 0.10 6,436 6,453 PROD1 DRILL DLOG P Tie in to RA, +1' correction 13:54 14:24 0.50 6,453 7,430 PROD1 DRILL WPRT P Wiper back in hole, 13K RIW 14:24 15:42 1.30 7,430 7,580 PROD1 DRILL DRLG P Drilling ahead, 1.3 BPM, 3900 CTP, 325 WHP, 4260 DHP, 10K RIW, 1- 2.5K DHWOB, 150 - 300 psi motor work, 80 -150 ROP. 15:42 16:42 1.00 7,580 6,400 PROD1 DRILL WPRT P Wiper to window. 16:42 19:00 2.30 6,400 6,400 PROD1 DRILL SFTY P Stand up safety meeting 19:00 19:45 0.75 6,400 7,580 PROD1 DRILL WPRT P RIH to drill 19:45 21:15 1.50 7,580 7,730 PROD1 DRILL DRLG P Drill Ahead 100 FPH, 1.3 BPM in, 1.2 BPM out, 4300 CTP, 335 WHP, 4390 BHP, 1 -1.5 DHWOB 21:15 22:15 1.00 7,730 6,430 PROD1 DRILL WPRT P Wiper trip back to window, 24K PUW 22:15 23:15 1.00 6,430 7,500 PROD1 DRILL WPRT P Running in hole set down weight at 7165, 7245, 7460,. PUH to 7000' working areas. Looked good. RIH to drill 23:15 23:45 0.50 7,500 7,730 PROD1 DRILL WPRT P Start sending new mud down hole. Cont. RIH 23:45 00:00 0.25 7,730 7,746 PROD1 DRILL DRLG P Drill Ahead 100 FPH, 1.37 BPM in, 1.27 BPM out, 4300 CTP, 335 WHP, 4390 BHP, 1 -1.5 DHWOB, 13.5 ECD 02/04/2010 Drill L1 Lateral from 7746' to 8747'. Swap out drilling mud 00:00 01:30 1.50 7,746 7,880 PROD1 DRILL DRLG P Drill Ahead 100 FPH, 1.37 BPM in, 1.27 BPM out, 4200 CTP, 390 WHP, 4340 BHP, 1 -1.5K DHWOB, 13.3 ECD, New mud around 01:30 02:15 0.75 7,880 7,880 PROD1 DRILL WPRT P Wiper trip to window, 26K PUW 02:15 02:21 0.10 6,450 6,450 PROD1 DRILL DLOG P Drop pump rate to mnimum rate, trap psi at MP choke, tie in depth to RA marker, no correction 02:21 03:00 0.65 6,450 7,880 PROD1 DRILL WPRT P RIH to drill Page 13 of 25 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:00 04:30 1.50 7,880 8,030 PROD1 DRILL DRLG P Drill Ahead 100 FPH, 1.37 BPM in, 1.27 BPM out, 4200 CTP, 420 WHP, 4340 BHP, 1 -1.5K DHWOB, 13.6 ECD 04:30 06:18 1.80 8,030 8,030 PROD1 DRILL WPRT P Wiper trip to window, 24K PUW 06:18 08:36 2.30 8,030 8,180 PROD1 DRILL DRLG P Drill Ahead 1.3 BPM, 4000 CTP, 420 WHP, 4320 BHP, 13.6 ECD, 1 -3K WOB, 200 - 300 psi motor work, 08:36 10:36 2.00 8,180 8,180 PROD1 DRILL WPRT P Wiper to window, 21K PUW, 11K RIW through build 10:36 12:18 1.70 8,180 8,330 PROD1 DRILL DRLG P Drill Ahead 1.3 BPM, 3900 CTP, 400 WHP, 4320 BHP, 13.6 ECD, 7K RIW, 1 -3K WOB, 200 - 300 psi motor work, 12:18 14:36 2.30 8,330 8,330 PROD1 DRILL WPRT P Wiper to window, 21K PUW, Tie in to RA, +1', Wiper back in hole, 12K RIW in build. 14:36 16:36 2.00 8,330 8,480 PROD1 DRILL DRLG P Drill Ahead 1.3 BPM, 3900 CTP, 3500 WHP, 4300 BHP, 13.6 ECD, 6K RIW, 1 -3K WOB, 200 - 300 psi motor work, 16:36 19:09 2.55 8,480 8,480 PROD1 DRILL WPRT P Wiper tripto window, 23K PUW 19:09 20:39 1.50 8,480 8,630 PROD1 DRILL DRLG P Drill Ahead 100 FPH 1.3 BPM in 1.23 BPM out, 4100 CTP, 400 WHP, 4318 BHP, 13.6 ECD, 5 -6K RIW, 1.5K DHWOB, 200 - 300 psi motor work, 20:39 22:54 2.25 8,630 8,630 PROD1 DRILL WPRT P Wiper Trip to window, 23K PUW 22:54 00:00 1.10 8,630 8,747 PROD1 DRILL DRLG P Drill Ahead 100 FPH, 1.3 BPM in, 1.2 BPM out, 3 -4K CTW, 4150 CTP, 410 WHP, 4350 BHP, 1.5 -2K DHWOB, 13.6 ECD 02/05/2010 Drill L1 Lateral from 8747' to 00:00 00:18 0.30 8,747 8,780 PROD1 DRILL DRLG P Drill Ahead 100 FPH, 1.3 BPM in, 1.2 BPM out, 3 -4K CTW, 4150 CTP, 470 WHP, 4409 BHP, 1.5 -2K DHWOB, 13.7 ECD 00:18 02:03 1.75 8,780 6,450 PROD1 DRILL WPRT P Wiper trip back to window, 26K PUW 02:03 02:18 0.25 6,450 6,452 PROD1 DRILL DLOG P Tie in depth to RA marker, Correction +2' 02:18 03:33 1.25 6,452 8,780 PROD1 DRILL WPRT P RIH to drill 03:33 04:18 0.75 8,780 8,857 PROD1 DRILL DRLG P Drill Ahead 100 FPH, 1.3 BPM in, 1.2 BPM out, 3 -4K CTW, 4150 CTP, 480 WHP, 4420 BHP, 1.4 -2K DHWOB, 13.8 ECD 04:18 04:33 0.25 8,857 8,857 PROD1 DRILL WPRT P Lose WOB, surface weight stacking, PUH BHA Wiper, 23K PUW. At 8760' RIH to drill, stack weight, PUH over pull 38K. RIH to nuetral weight. Pop free, PUH 22K. PUH 50'. RIH to drill. Page 14 of 25 1 ! • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:33 09:09 4.60 8,857 8,930 PROD1 DRILL DRLG P Drill Ahead 30 FPH, 1.3 BPM in, 1.2 BPM out, 2 -2.2K WOB, 4110 CTP, 480 WHP, 4422 BHP, 13.9 ECD. Drilled into hard stringer. ROP increased at 8900' to 50 +. 09:09 12:00 2.85 8,930 8,930 PROD1 DRILL WPRT P Wiper trip to window, 20K PUW, 12:00 12:54 0.90 8,930 9,018 PROD1 DRILL DRLG P Drill Ahead 1.3 BPM, 4000 CTP, 500 WHP, 4440 BHP, 13.99 ECD, 4K RIW, 1 -3K WOB, 200 - 300 psi motor work, 12:54 13:54 1.00 9,018 9,018 PROD1 DRILL WPRT P Geo -wiper 13:54 14:42 0.80 9,018 9,080 PROD1 DRILL DRLG P Drill Ahead 1.3 BPM, 4000 CTP, 410 WHP, 4400 BHP, 4K RIW, 3K WOB, 200 - 300 psi motor work, 14:42 17:42 3.00 9,080 9,080 PROD1 DRILL WPRT P Wiper to window, 21K PUW 17:42 19:57 2.25 9,080 9,255 PROD1 DRILL DRLG P Drill Ahead 80 -100 FPH, 1.3 BPM in, 1.2 BPM out, 4390 BHP, 13.9 ECD, 1.1.8K DHWOB 19:57 23:27 3.50 9,255 9,255 PROD1 DRILL WPRT P Wiper Trip to window, 23K PUW 23:27 00:00 0.55 9,255 9,305 PROD1 DRILL DRLG P Drill Ahead 80 -100 FPH, 1.3 BPM in, 1.2 BPM out, 4250 CTP, 370 WHP, 4390 BHP, 13.9 ECD, 1.1.8K DHWOB 02/06/2010 TD L1 Lateral 9437'. PU /MU liner, RIH, Billet unable to pass through window. POOH 00:00 00:30 0.50 9,305 9,305 PROD1 DRILL WPRT P PU BHA Wiper, 20K PUW 00:30 02:30 2.00 9,305 9,435 PROD1 DRILL DRLG P Drill Ahead 60 FPH, 1.3 BPM in, 1.2 BPM out, -4K CTW, 4250 CTP, 310 WHP, 4470 BHP, 13.9 ECD 02:30 06:30 4.00 9,435 9,437 PROD1 DRILL WPRT P TD well 9435'. Wiper trip back to window, 24K PUW, Tie in depth at window to RA marker, +3'. 06:30 10:30 4.00 9,437 0 PROD1 DRILL DISP P Lay in liner running pill from TD. Lay in 13.1 KWF from window to surface 10:30 12:00 1.50 0 0 PROD1 DRILL PULD P Confirm no flow at surface, LD drilling BHA 12:00 12:30 0.50 0 0 COMPZ CASING PUTB P RU for liner job 12:30 12:42 0.20 0 0 COMPZ CASING SFTY P PJSM for running liner 12:42 16:30 3.80 0 1,931 COMPZ CASING PUTB P Start PU and run liner, 59 Joints and a couple of pups. 16:30 17:30 1.00 1,931 6,267 COMPZ CASING RUNL P RIH, EDC open 17:30 18:30 1.00 6,267 6,267 COMPZ CASING RUNL P Tie into EOP flag -1.7'. Close EDC RIH 20 FPM through window, Increase to 50 FPM. 18:30 19:00 0.50 8,298 8,298 COMPZ CASING RUNL T Tag 8298'. PUH 27K PUW, RIH 60 FPM, Tag, PUH 27K PUW. Tagging on billet. RIH 15 FPM tag. All tags 8298'. 19:00 19:45 0.75 8,298 7,298 COMPZ CASING RUNL T Billet not passing through window. POOH pumping across top. Page 15 of 25 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:45 20:00 0.25 7,298 8,270 COMPZ CASING RUNL T Stop for flow check. Well flowing. RIH 8270' placing EDC as low as possible wirth tagging billet in window. 20:00 20:45 0.75 8,270 8,270 COMPZ CASING CIRC T Circulate KWF bottoms up through EDC, 20 bbls out, 20:45 21:30 0.75 8,270 7,372 COMPZ CASING RUNL T Start POOH 20 FPM, pumping .6 BPM, 21:30 22:30 1.00 7,372 6,309 COMPZ CASING RUNL T Bottoms up at surface, stop for flow check, No flow. Continue POOH .6 BPM in, .48 BPM out. 22:30 23:51 1.35 6,309 0 COMPZ CASING RUNL T Paint EOP flag, Conitnue POOH 23:51 00:00 0.15 0 0 COMPZ CASING RUNL T At surface, Perform flow check 02/07/2010 RIH 2nd attempt with liner without Billet/Knuckle Joint and 1 joint STL liner. Set liner on bottom.(9438.16) TOL 7591'. Swap hole over to 10ppg Flo -Pro, POOH. 2 week BOP test. 00:00 00:30 0.50 0 0 COMPZ CASING OWFF T Peform flow. Well flowed .75 bbrls in 15 minutes. Shut in well, pressured up 4 psi in 10 minutes. Hold safety meeting bull heading KWF. 00:30 01:30 1.00 0 0 COMPZ CASING CIRC T Line up to bull head 10 bbrls 13.1 ppg new KWF of truck. Sample off truck weight 13.1 ppg. 01:30 01:45 0.25 0 0 COMPZ CASING OWFF T Shut down flow check 15 minutes. No flow, 0 WHP. 01:45 02:45 1.00 0 0 COMPZ CASING PUTB T Lay down BHA, break out billet, knuckle joint and one joint of STL. 02:45 03:30 0.75 0 0 COMPZ CASING PUTB T Marks on the billet indicating tagging up in Window. Knuckle joint possible cause. Remove billet, knuckle joint and one stick of STL. MU injector head to liner. Summary:Tagging up at 8298' bit depth. 1889' =Bit to Knuckle joint. This= 6409'. TOW = 6409', BOW= 6419'. Add Billet Knuckle joint and X -over = 6420', depth tagging up at BOW. 03:30 05:00 1.50 0 1,890 COMPZ CASING RUNL T RIH with liner 05:00 06:00 1.00 1,890 6,268 COMPZ CASING RUNL T Tie depth into EOP flag. -3' correction, Close EDC, record up and down weights, RIH 10K, PUW 20K, RIH 06:00 06:30 0.50 6,268 9,437 COMPZ CASING RUNL T Run liner to TD, Stacked — 6K while deployment sleeve was going out the window. Tagged bottom at 9437' set down 5K WOB. Online with pump at 1.2 BPM, PUH, released from liner, lost 6.5K up weight. Liner top at 7590' 06:30 07:00 0.50 9,437 6,400 COMPZ CASING RUNL P POOH to window 07:00 08:36 1.60 6,400 6,400 COMPZ CASING DISP P Circulate 13.1 KWF out of hole with a 25 Bbls spacer and flo -pro, maintaining 1:1 returns and BHP did not exceed 4350 psi Page 16 of 25 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T ' Comment 08:36 10:00 1.40 6,400 0 COMPZ CASING TRIP P POOH following MPD tripping schedule for 10.0 flo -pro 10:00 10:18 0.30 0 0 COMPZ CASING SFTY P PJSM for undeploy liner running BHA 10:18 11:48 1.50 0 0 COMPZ CASING PUTB P Undeploy BHA 11:48 13:48 2.00 0 0 COMPZ WHDBO SVRG P Grease tree, prep for BOP testing 13:48 14:00 0.20 0 0 COMPZ WHDBO SFTY P PJSM for testing BOP 14:00 00:00 10.00 0 0 COMPZ WHDBO BOPE P Testing BOP 02/08/2010 Complete 2 week BOP testing, RIH to dress window, Stuck BHA in window, Disconnect. Attempt to fish BHA. Unsuccessful. POOH 00:00 01:00 1.00 0 0 COMPZ WHPST SVRG P Clean gripper blocks on injector head, Clean up floor, LD BOP test joint, prepare safety joint with TIW valve. Displace reel back to Flo -Pro. 01:00 03:00 2.00 0 0 COMPZ WHDBO BOPE T Change stripper rubber, remove check valves in drilling head. Test Inner reel valve and stripper rubber. * * ** *BOP test complete * * * * * ** * * * *2 hours down time. Exceeded 10 hours * * * * * * * * ** 03:00 04:00 1.00 0 0 COMPZ WHPST PULD P Reconfigure BHA, Add HOT, Load BHA into PDL, Install check valves, Align valves on rig preparing for Deployment. 04:00 04:18 0.30 0 0 COMPZ WHPST SFTY T PJSM pressure deploying 04:18 06:18 2.00 0 0 COMPZ WHPST PULD T Deploy BHA #18, 2.74 window mill, 2.8 string mill, .4 AKO 06:18 07:24 1.10 0 6,250 COMPZ WHPST TRIP T RIH 07:24 07:48 0.40 6,250 6,300 COMPZ WHPST DLOG T Tie in, -4' 07:48 08:00 0.20 6,300 6,408 COMPZ WHPST MILL T RIH, start time milling at 6408' at 2 FPH, 1.4 BPM, 4000 CTP, 500 WHP, 4190 BHP, 20K PUW, 11K RIW 08:00 09:00 1.00 6,408 6,410 PROD1 WHPST MILL T Continue time milling, at 6409' started to get motor work, stalled at 6410', 21K PUW. Resume time milling from 6409.5 @ 0.6 FPH. 09:00 11:00 2.00 6,410 6,411 PROD1 WHPST MILL T Increased ROP to 0.9 FPH, had one pressure spike that drilled off immediatly. Continued to 6911' Stalled and unable to PUH. Pulled to 39K which was -20K WOB. 11:00 12:18 1.30 6,411 6,353 PROD1 WHPST TRIP T Attempted to free mill. Tried to orient , pull up , slack off, pressure up with no movement. 6410.5 with 4K WOB, 6407.8 with -17K WOB. Consulted with town engineers and decided to disconnect. 12:18 13:30 1.20 6,353 0 PROD1 WHPST TRIP T POOH, left 57.2' of fish in the hole with top of fish at —6353' Page 17 of 25 • Time Logs From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:30 14:00 0.50 0 0 PROD1 WHPST PULD T Lay down whets left of the BHA 14:00 15:00 1.00 0 0 PROD1 WHPST SVRG T Service rig while waiting for fishing tools 15:00 17:00 2.00 0 0 PROD1 WHPST PULD T PU fishing tools, MU BHA into PDL and deploy BHA # 19 17:00 18:15 1.25 0 6,300 PROD1 WHPST TRIP T Close EDC, RIH 18:15 18:30 0.25 6,300 6,359 PROD1 WHPST FISH T Record up and down weights, 20K up, 12K down. Start circulating 1.3 BPM jetting down to fish. Drop rate down to .5 BPM. Latch into fish. Shut down pumps, PUH confirming latched into fish. 25K PUW 18:30 19:00 0.50 6,359 6,355 PROD1 WHPST FISH T Start jarring: RIH to cock jars Down: 5K WOB, 8K CTW PUH: -5K WOB, 25K CTW 6 Times, No Luck Jars did not fire first time 19:00 19:30 0.50 6,359 6,355 PROD1 WHPST FISH T Increase Parameters: Down: 3 -4K WOB, 8K CTW PUH: -10K WOB, 27K CTW 5 times, No Luck 19:30 20:00 0.50 6,359 6,355 PROD1 WHPST FISH T Increase Parameters: Down: 2.5 -3K WOB, 10K CTW, 6359 PUH: -12K WOB, 29K CTW, 6353.5 5 Times, No Luck 20:00 20:30 0.50 6,359 6,355 PROD1 WHPST FISH T Increase Parameters: Down: 3 -3.5K WOB, 9 -10K CTW 6358 PUH: -.13 WOB, 30 -33K CTW, 6354.2 5 Times, No Luck 20:30 21:00 0.50 6,359 6,355 PROD1 WHPST FISH T Increase Parameters: Down: 3 -3.5K WOB, 11K CTW, 6358.7' PUH: -16 WOB, 35K CTW Jars POP: -15K WOB, PUH to 40K CTW after jars popped to 6352.6' 5 Times, No Luck 21:00 22:00 1.00 6,359 6,355 PROD1 WHPST FISH T Increase Parameters: Down: 3 -3.5K WOB, 11 -12K CTW, 6358.7' PUH: -18K WOB, 35 -36K CTW, 6352.6 PUH to 40K CTW after jars fire, -20K WOB. 5 Times No Luck Page 18 of 25 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:00 22:30 0.50 6,359 6,355 PROD1 WHPST FISH T Lower Parameters: Down: 3 -3.5K WOB, 11 -12K CTW 6358' PUH: -15 to -16K WOB, 35 -36K CTW Jars fire: -13 to -14K WOB, 34K CTW PUH to 40K CTW, -20 WOB 6352.1' 4 Times, No luck 22:30 22:51 0.35 6,359 6,355 PROD1 WHPST FISH T Jars not firing after 2 more attempts. 37 total attempts. Jars did not fire 3 times. Online with pumps to disconnect off of fish. Unable to disconnect. Not getting in differential pressure on BHA. Cycle EDC open and closed to assure EDC is closed 22:51 00:00 1.15 6,359 0 PROD1 WHPST TRIP T Disconnect from fish. POOH Having another set of jars brought out from Dead Horse. 02/09/2010 BHA# 20 - JAR on fish total of 66 hits. No luck. POOH and cut off 130 ft of CT. RIH with Hip tripper. tag 6358'. Good action on BHA. 00:00 01:15 1.25 4,500 0 PROD1 WHPST TRIP T Continue POOH 01:15 01:30 0.25 0 0 PROD1 WHPST SFTY T PJSM undeploy BHA # 19 01:30 03:30 2.00 0 0 PROD1 WHPST PULD T Undeploy BHA #19, Deploy BHA # 20 03:30 04:54 1.40 0 6,360 PROD1 WHPST TRIP T RIH 04:54 05:24 0.50 6,360 6,360 PROD1 WHPST FISH T Weight check, 17K PUW, 12 RIW, zero WOB, pumping at 1.2 BPM, 4000 CTP. Latch into fish at 6360', start jarirng at -7K WOB 6360.4 = 3K WOB, 6356.7 = -7K, Jar 4X 05:24 08:39 3.25 6,360 6,360 PROD1 WHPST FISH T Increased up weight to -10K at 6356.0'. After jars fire straight pull to -18K at 6353.3', 39K CTW Jar 28X, Pump off fish 69 Total attempts, 66 jars firing on both runs, 3 jars not going off in run #1 08:39 09:39 1.00 6,360 6,360 PROD1 WHPST FISH T Wait on Orders, Discuss with Town. 09:39 11:00 1.35 6,360 0 PROD1 WHPST FISH T At Surface 11:00 12:30 1.50 0 0 PROD1 WHPST FISH T PJSM Undeploy BHA # 20, Deploy BHA #21 12:30 12:45 0.25 0 0 PROD1 WHPST FISH T PJSM, cutting CT 12:45 13:30 0.75 0 0 PROD1 WHPST SLPC T Cut CTC off, RU floor for cutting CT 13:30 14:45 1.25 0 0 PROD1 WHPST SLPC T Start Cutting CT 14:45 15:06 0.35 0 0 PROD1 WHPST CIRC T Stab onto well, reverse circulate pumping slack back Page 19 of 25 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:06 15:36 0.50 0 0 PROD1 WHPST SLPC T Lift off well cut CT back to find cable. Cut 130' CT 15:36 16:06 0.50 0 0 PROD1 WHPST SLPC T MU CTC 16:06 16:51 0.75 0 0 PROD1 WHPST SLPC T Pull test CTC 30K good, Head up BHI drilling head 16:51 17:06 0.25 0 0 PROD1 WHPST SFTY T Hold PJSM deploying 17:06 19:06 2.00 0 0 PROD1 WHPST PULD T Deploy BHA #21 19:06 21:06 2.00 0 6,359 PROD1 WHPST TRIP T Test Hip tripper prior to RIH- good - RIH with EDC open. Stop @ 6264' Close EDC. P/U weight 18K. Tag Fish @ 6358.5' 21:06 22:36 1.50 6,359 6,350 PROD1 WHPST FISH T Sit down 4K, P/U 5K over to 23K. Start pumping .3 bpm. Increase to . 7 bpm, getting good vibration on BHA sensor. Lost pressure readings on BHA. P/U weight to 28K at surface. Feel the vibration on CT string. Hammer is working @ .6 bpm, circ press 2800 psi, WHP 700 psi, BHP 4170, out rate .4 bpm. 22:36 00:00 1.40 6,350 6,354 PROD1 WHPST FISH T Slowly moving or stretch @ 35 - 44K surface weight and pumping .5 bpm. up to 6350.55'. Work it for 30 minutes. No luck. RIH and set down to20K 3 ft early © 6354. Tap down. P/U to 44K, 6350.2. RIH, sat down @ 6353.2, P/U 46K to 6349.75'. 02/10/2010 Continue with Hip- tripper, moved fish roughly 3 ft. POOH, pump slack out of CT string (278') of E -line. RIH with fishing BHA, recovered fish on 3rd hit - max. straight pull 32K at surface. POOH lay down fish. 00:00 01:30 1.50 6,354 6,349 PROD1 WHPST FISH T Continue hip tripping operations. .5 bpm, circ 2800 psi, WHP 700, working fish from 6354.5 - 17K up to 6349.4' - 45K. 01:30 03:00 1.50 6,354 6,354 PROD1 WHPST FISH T Increase pump rate to 1.1 bpm, circ 4200 psi, max. pull 45K, 6349.1', set down to 22K @ 6353.7'. Good work on hip tripper. Cylce two more times. Come down off pumps. Cycle dry - 6349.5 to 6354.5'. May have moved it up 3 ft. 03:00 03:30 0.50 6,355 6,350 PROD1 WHPST FISH T Pumped off fish, pushed it down 2 ft 6355.7 in order to get off. P/U weight 18K off fish pumping 1.2 bpm. Call town & decide to latch and try again.RIH dry latch - 6356', P/U 45 K 6350'. 03:30 05:00 1.50 6,350 6,346 PROD1 WHPST FISH T Start pumping .6 bpm, 3000 psi, P/U weight 44K, @ 6349.5', WHP 700 psi, BHP 4180psi. Hip tripper failed after 10 minutes of action. Disconnect @ 6356' and prepare to kill well. Open EDC 05:00 06:00 1.00 6,346 6,346 PROD1 WHPST CIRC T Begin Pumping 10 bbl drill mud Visc pill followed by 13.1# Formate. Page 20 of 25 • 1110 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 08:00 2.00 6,346 0 PROD1 WHPST TRIP T POOH 08:00 09:15 1.25 0 0 PROD1 WHPST OWFF T PJSM LD BHA, Perform flow check, Well flowing. Bull Head 3 bbrls 13.1 Formate. .25 BPM. 650psi WHP. Perform Flow check. Well Flowing Bullhead 10bbrls 13.1 Formate, perform flow check. No Flow.. 09:15 11:45 2.50 0 0 PROD1 WHPST PULD T LD Tools, RU to pump slack out of CT, pump 35 bbrls pumping slack forward out of reel. 1.8 BPM 4500psi CTP. 11:45 12:45 1.00 0 0 PROD1 WHPST SLPC T Pop off well, LD C/S hydril joint, Measure cable pumped out of CT. Cut E -line with 15' hanging out of end of CTC, pull test CTC and pressure test. 278' of cable pumped out of CT. 12:45 14:15 1.50 0 0 PROD1 WHPST SVRG T Hold PJSM, MU fishing assembly, hang into well, Service reel and Injector head cleaning gripper blocks, while waiting on drill collars 14:15 15:30 1.25 0 187 PROD1 WHPST PULD T MU BHA, Fishing assemply with 3 Drill Collars and 3 C/S Hydrill joints. Total Length Fishing BHA = 186.57' 15:30 17:00 1.50 187 6,358 PROD1 WHPST TRIP T RIH, Record up and down weights 20.5K CTW up, RIH 13K. RIH to latch into fish 17:00 18:00 1.00 6,358 6,358 PROD1 WHPST FISH T Latch into fish 6358', Pick up to fire jars 23K CTW. Held for 15 minutes no fire. RIH to 6363', push down 3 ft? . Wait on crew change. 18:00 19:00 1.00 6,358 6,359 PROD1 WHPST FISH T P/U to 24K 6359.4'. Not sure if jars are cocked due to +3 ft slide. Tool slowly sliding up to 6358.6' - no fire on jars. RIH 6364'.34 - tagged. Set down to set jars. P/U to 24K - 6359.16' - soft hit 7 minutes in - P/U to 30K - Something pulled free. @ 32K overpull - 6358.81'. CT weight 22K - Came up 6334.33' overpull drag 25K, 6298.44' drag, 6232' drag. Pulled up 100'. Stop. 19:00 22:00 3.00 6,359 210 PROD1 WHPST TRIP T Set up to pump down Backside with KWF while POOH. 30 fpm with fish. 22:00 00:00 2.00 210 0 PROD1 WHPST PULL T Pre -job safety meeting, lay down fishing BHA. Fish recovered @ surface. Some light marks on mill & string mill. 02/11/2010 Pump slack in CT string. Cut back 221' to find cable. RIH with Crayola BHA to dress window. Recover KWF & start dressin window @ 6408'. 00:00 01:00 1.00 0 0 PROD1 WHPST CTOP T Complete breaking down BHA at surface. 01:00 02:00 1.00 0 0 PROD1 WHPST SFTY T Discussion for plan forward and prepare CT string for slack MNGT. Page 21 of 25 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:00 04:30 2.50 0 0 PROD1 WHPST SLPC T Start pumping slack back into CT string, pumped 45 bbls. Cut back 221 ft of CT to find cable. Tested Cable to ensure still good. 04:30 06:00 1.50 0 0 PROD1 WHPST PULD T Start re- heading CT connector & made up BHA # 23 with 1.25 AKO, jar & 2.74" Crayola mill on pipe skate. 06:00 07:30 1.50 0 0 PROD1 WHPST PULD T Lift off well, Reconfigure BHA, MU 10' PUP joint into milling string, Town request 07:30 08:45 1.25 0 0 PROD1 WHPST PULD T Lift off well to remove JARS from BHA as per town 08:45 10:00 1.25 0 0 PROD1 WHPST PULD T Surface test Coil Track, WOB sensor not working PJSM, lift off well to replace WOB sensor in BHA * * * * * ** *BHA downtime, replacing WOB sensor in BHA * * * * * * * * * ** 10:00 10:27 0.45 0 0 PROD1 WHPST CIRC T Pump slack forward 10:27 11:57 1.50 0 6,248 PROD1 WHPST TRIP T RIH 11:57 12:12 0.25 6,260 6,264 PROD1 WHPST DLOG T Tie in depth, correction -4' 12:12 14:27 2.25 6,399 6,399 PROD1 WHPST WPST T Displace well to Flo -Pro 14:27 14:39 0.20 6,400 6,408 PROD1 WHPST WPST T Record up and down weights 18K up, 9K down, 14:39 19:15 4.60 6,408 6,415 PROD1 WHPST WPST T Start auto drilling 2' /hour down highside 19:15 20:45 1.50 6,415 6,419 PROD1 WHPST WPST T Starting to get motor work @ 6418' - WOB .7, 1.4 bpm, 3700 psi, WHP 430, ROP 2 fph. Starting to get metal returns to surface on magnet. 20:45 22:45 2.00 6,419 6,420 PROD1 WHPST WPST T Had a stall @6418.9 going 2 fph. Stop pumping P/U weight 18K, RIH slowly down to 6418.7 - start milling again. Good even motor work. Another stall @ 6419.09'. Good motor work back on bottom. ROP 2 -3 fph, WOB 1.0 circ pressure 3900psi. Could not transfer weight to bit @ 6419.8' P/U and slide down a little quicker. 22:45 00:00 1.25 6,420 6,420 PROD1 WHPST WPST T Continue milling ahead, definate hard bottom. 1.4 WOB, circ press. 3950psi, slow milling. Getting slow drill offs. Metal cuttings across shakers & no cement. 02/12/2010 Continue dressing window with 2.74" crayola mill. No progress past 6420'. POOH inspect BHA, change to 2.0 AKO. RIH continue dressing window, drifted through 1 time @ 30 fpm. Could not make it through again. Dress window down to 6421.6'. POOH Page 22 of 25 r i Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 02:00 2.00 6,420 6,420 PROD1 WHPST WPST T Continue to slowly mill off window ledge @ 6419 -6420. P/U to 6405' and orientate due to torque, no stall. Looks very clean running back down to 6419.8'. Continue to try mill ahead. 02:00 03:00 1.00 6,420 6,420 PROD1 WHPST WPST T Call town - Not making any footage. P /U, slow pump rate to .5 bpm, and try to RIH quicker to see if we can slide by. Tagged 6421.8' P/U and RIH 5 fph to top of tag and begin milling agian. Definate notice of motor work and reactive torque. WOB 1.9, circ press. 4000 psi, 1.35 bpm. but making very little footage. No metal cutting over shakers, cannot make any progress. 03:00 05:00 2.00 6,420 72 PROD1 WHPST WPST T POOH pumping 1.4 bpm to inspect BHA. - lots of metal shavings over shaker 800 ft from surface. Some light yellow & blue paint chips & looks like small pieces of rubber. 05:00 06:30 1.50 72 0 PROD1 WHPST WPST T Safety meeting and Undeploy BHA. Perfrom maint. on MP choke. 06:30 08:30 2.00 0 0 PROD1 WHPST WPST T Discuss with town on next BHA, service injector head, clean gripper blocks. Mill OOH, 2.74NO -GO, 2.73 -GO, indents on motor 42.5" Up from mill on motor. No wear on mill. 08:30 10:00 1.50 0 0 PROD1 WHPST PULD T PJSM, MU BHA 23, Deploy 10:00 11:45 1.75 0 6,260 PROD1 WHPST TRIP T RIH 11:45 12:00 0.25 6,278 6,400 PROD1 WHPST DLOG T Tie in depth -5 Correction, close EDC, RIH 12:00 13:30 1.50 6,400 6,421 PROD1 WHPST TRIP T RIH drifting window without pumps at different TF: HS tag at 6417, LS tag at 6418, 30R tag 6416, 30L tag 6416, 90R tag 6421, 45R tag 6414, 130R tag 6421, 15L tag 6416, 30L tag 6416, 45L tag 6416, 60L tag 6415, 45L tag 6416, 60L tag 6415, 90L tag 6421, 105L tag 6421, 75L tag 6421, 120L tag 6421, 135L tag 6421, 150L tag 6421, 180L tag 6421, 165L tag 6421, 90R tag 6421 13:30 13:45 0.25 6,421 6,438 PROD1 WHPST TRIP T RIH HS 30' /minute, pop through window. RIH to 6438 13:45 14:12 0.45 6,421 6,421 PROD1 WHPST MILL T Back ream window 3' /hour starting at 6422', start getting motor work at 6421', slow down to 1' /hour 14:12 18:12 4.00 6,420 6,420 PROD1 WHPST MILL T Increase ROP to 3' /hour. 3900 CTP, 1.38 BPM in, 1.3 BPM out, 431 WHP, 13.3 ECD, 17K CTW. Stall @ 6415' - P/U and continue milling from 6414' Page 23 of 25 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:12 19:42 1.50 6,420 6,421 PROD1 WHPST MILL T 6420.56' Good weight transfer with light motor work. Same as last night. CT weight 8k, WOB 1.6, circ press. 4000psi, 1.40 bpm. Work it for 30 minutes, decision made to P/U and dry run through it @ 30 fpm. Tagged first time @ 6422.5', P/U RIH tagged @ 6419' had over -pull 25K coming up. Start milling down from 6414', no motor work detected until 6420.6' Milling slowly for 30 minutes. 19:42 21:42 2.00 6,421 6,420 PROD1 WHPST MILL T Some light metal shavings, yellow & blue paint chips (more than last night). Small thin shaving of rubber. P/U & try dry run through it again. Tagged 1 OR @ 6417'. Tagged 6421.5 - 5 left, tag 6416 - 15 R, 6.421' HS, tag 6416' HS, tag 6416 5L, tag 6421 HS, all @ 30 fpm. 21:42 23:00 1.30 6,421 6,421 PROD1 WHPST MILL T Establish a milling rate and RIH slowly from 6414' - starting seeing motor work @ 6420.8'. Mill for 1 hour no changes. 23:00 00:00 1.00 6,421 6,300 PROD1 WHPST TRIP T Try to Dry run @ 35 fpm, HS, 10R, 15, R all tagged @ 6421.6'. POOH for LIB run pumping through EDC. 02/13/2010 Made two LIB runs 2.77" & 2.70" "Fish left in well" Lead from 2.70" LIB depth 6421' BOW. Swap well to SW & freeze protect from 2800' to surface. 1300 psi left on well. Prepare for rig move. 00:00 01:30 1.50 3,500 72 PROD1 WHPST TRIP T POOH for LIB run 01:30 03:00 1.50 72 72 PROD1 WHPST PULD T Safety meeting & undeploy BHA. 03:00 04:30 1.50 0 54 PROD1 WHPST PULD T Scribe BHA, remove motor & mill. Install 2.77" LIB block. 04:30 06:00 1.50 54 6,250 PROD1 WHPST TRIP T RIH 06:00 06:15 0.25 6,250 6,274 PROD1 WHPST DLOG T Tie in depth -5/correction, Close EDC, RIH 06:15 06:30 0.25 6,274 6,417 PROD1 WHPST TRIP T Tag with LIB, 2K WOB, 06:30 08:00 1.50 6,417 0 PROD1 WHPST TRIP T POOH 08:00 09:30 1.50 0 0 PROD1 WHPST PULD T PJSM. Undeploy BHA 25 09:30 10:45 1.25 0 0 PROD1 WHPST OTHR T Nothing on LIB face. Discuss in conference call for next run 10:45 12:15 1.50 0 0 PROD1 WHPST PULD T MU 2.7" LIB Deploy BHA 26 12:15 13:30 1.25 0 6,250 PROD1 WHPST TRIP T RIH 13:30 13:45 0.25 6,250 6,274 PROD1 WHPST DLOG T Tie in depth, -5'. RIH 13:45 14:00 0.25 6,274 6,420 PROD1 WHPST TRIP T RIH 20' /minute HS, tagging at 6420.5', 5.8K DHWOB 14:00 15:30 1.50 6,394 0 PROD1 WHPST TRIP T PUH 18K CTW, open EDC, POOH 15:30 17:00 1.50 0 0 PROD1 WHPST PULD T PJSM, undeploy BHA 26 Page 24of25 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 0 0 PROD1 WHPST OTHR T Inspect LIB, * Fish left in well* 2.70" Lead from LIB fell off in well. call town to discuss. 17:00 19:30 2.50 22 22 DEMOB WELLPF TRIP P Prepare to RIH to swap hole over to sea water. Break down BHA & P/U short BHA for SW /diesel swap. Prepare for rig move. 19:30 23:30 4.00 6,300 2,800 DEMOB WELLPF TRIP P RIH down to 6300', circulating SW in well. POOH, stop @ 2800 ft and lay in Diesel fro freeze protect while POOH. 30 bbls pumped. 23:30 00:00 0.50 2,800 0 DEMOB WELLPF PULD P CT @ surface. Safety meeting, Close master valve and lay down BHA. 1300 psi WHP. 02/14/2010 Rig Release @ 12:00 Noon 00:00 01:00 1.00 0 0 DEMOB WELLPF PULD P Break down BHA, P/U stinger bar for flushing stack and BOPE lines. 01:00 02:00 1.00 0 0 DEMOB WHDBO CIRC P Flush stack and lines, start rigging up BPV equipment. 02:00 03:00 1.00 0 0 DEMOB WHDBO MPSP P Pressure test BPV lubricator using the BOP test pump with diesel. Set • BPV , diesel packed in well. 1350 psi on WH. Close swabb valves. Rig down BPV lubricator. 03:00 05:30 2.50 0 0 DEMOB MOVE CIRC P Blow down CT to pits 19 bbls back, blow down surface lines. Bring down Top drive to warm up. 05:30 12:00 6.50 0 0 DEMOB MOVE NUND P Crew Change, PJSM, RD rig Page25of25 Page l of l • Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Thursday, March 04, 2010 1:43 PM To: 'Ohlinger, James J' Subject: RE: 31-11L1 (PTD 209 -121) James, Go ahead and flow well to bring pressure down. Send 10-404 with the wellwork done to date, schematic and your plan forward. Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Ohlinger, James J [mailto: James .J.Ohlinger @conocophillips.com] Sent: Thursday, March 04, 2010 1:10 PM To: Schwartz, Guy L (DOA) Cc: Allsup- Drake, Sharon K Subject: 3I -11 We're bringing 31 -11 online to bring the reservoir pressure down before we go back out. It was 13.1 ppg when we drilled it, and we can only take the K- Formate to - 13.0ppg. I'm attaching the completion schematic, we basically have -1100' of open hole between the window and top of liner before the whipstock fell and we lost the window. Assuming we get AFE Revision approval from BP we won't be back to 31 -11 till the end of May. What do you need from me, i.e. 10-404 or is the 403 suspension good? James OFiinger CTD Engineer ConocoPhillips AK, Inc. 907 - 265 -1102 office 907 - 748 -1051 cell 3/4/2010 1 a0 (zl 31 -11 Suspended CTD Sidetrack - Status as of U 17- Feb -10 3 -1_ l o Camco TRMAXX -5E SSSV © 2212 MD (2.813" min ID, X- profile) 3 -1/2 ", 9.3# L -80 EUE 8rd -Mod Tubing to surface 16" 62# H -40 shoe @116' MD 3 -1/2" Camco MMG gas lift mandrels (5) @ 2512', 3702', 4760'. 5668', & 6074' 9 -5/8" 36# J -55 shoe @ 3383' MD • X' landing nipple @ 6123' MD (2.813" min ID) Baker 3-1/2" seal assembly 6131' - 6143' MD 80 -40 PBR at 6132' - 6145' Baker KBH Anchor Seal Assy at 6145' MD Baker SAB 40 -32 packer @ 6146' MD 'X' landing nipple @ 6156' MD (2.813" min ID) Holes shot in 3 -1/2" straddle at -6408' -6413' & 6213' MD Baker F1 permanent packer @ 6422' MD (e -line set) - 80 -40 Sealbore extension (6425'- 6430') 3 -1/2" straddle 'D' landing nipple @ 6433' MD (2.750" min ID) cemented in place WLEG @ 6438' MD FISH: 3 -1/2" °l • monobore w whipstock at 6422' (TOWS) _ __ ---- ___ - - L1 TD @ 9437' (A2 A sand perfs sand) A3: 6437' - 6454' A2: 6457' - 6486' FISH: 3 -1/2" monobore Top of 2 -3/8" slotted Al: 6494' - 6503' — liner - 7590' whipstock . Depth unknown 7" 26# J -55 shoe @ 6550' MD S DiF LtAlAspk, SEAN PARNELL, GOVERNOR AT �1 ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Mr. James Ohlinger CTD Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 31-11L1 Sundry Number: 310 -053 Dear Mr. Ohlinger: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unle rehearing has been requested. • ce ly, . e. ount ♦ r DATED this' day of February, 2010. Encl. ' �,,� (� (' STATE OF ALASKA RECEIVED * ali ' 3 ' ALAS IL AND GAS CONSERVATION COMMIS t iw APPLICATION FOR SUNDRY APPROVALS FEB 2 2 2V1 V 20 AAC 25.280 Alaska Oil & Caa C8112. Cammission 1. Type of Request: Abandon fl Rug for Redrill r Perforate New Pool r Repair well r Change A ram Suspend l Rug Perforations r Perforate r Pull Tubing r Time Extension Operational Shutdown rzi ! • Re -enter Susp. Well r Stimulate E Alter casing r Other: 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development • Exploratory r 209 -121 • 3. Address: Stratigraphic I Service 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50- 029 - 21932 -60 • 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes r No 31 -11L1 • 9. Property Designation: 10. Field /Pool(s): ADL 25523, 25631 Kuparuk River Field / Kuparuk River Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ff): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9437 6214 6422' Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 116' 116' SURFACE 3348 9.625 3383' 3383' PRODUCTION 6375 7 6408' 6141' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): none none none Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) no packer Camco SSSV 2212' MD, 2212' ND 12. Attachments: Description Summary of Proposal 17 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Development Service 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 2/14/2010 Oil P . Gas r WDSPL r Plugged 16. Verbal Approval: Date: WINJ r GINJ r WAG r Abandoned Commission Representative: GSTOR r SPLUG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: James Ohlinger @ 265 -1102 Printed Name James Ohlinger Title: CTD Engineer � /� / Signature Phone: 265 - 1102 Date �d Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness 3/bj' -1155 Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance Other: J� ,/ Subsequent Form Required: / 6, • I0 T C ct- re r� ft te Ss ale i % re Sk.." ......K.4..... ......K.4..... .. G 0 "' S APPROVED BY Ap. • • : .. COMMISSIONER THE COMMISSION Date: _ i I ,• It li 7 •rm 10 - 403 Revised 12/2009 t \ i N A L Z Submit�i D p lica e L o iy ConocoPhillips Alaska, Inc. Drilling & Wells ConocoPhillips Coiled Tubing Drilling Alaska 3I - 11L1 CTD Suspension Engineer: James Ohlinger CT Drilling Engineer (907) 265 -1102 Well Permit # Objective API # 3I -11L1: 209 -1210 A2 -Sand 50 -029- 21932 -60 . 3I- 11L1 -01: 209 -1220 Al -Sand 50- 029 - 21932 -61 3I- 11L1 -02: 209 -1230 A3 -Sand 50 -029- 21932 -62 Description: Nabors CDR2 -AC rigged up on Well 3I -11 on 1/24/10 to drill a tri- lateral CTD Sidetrack. Between the rig -up and 2/6/10, the L1 lateral was drilled. On February 6 CDR2 -AC proceeded to run liner from TD- 9,437' up to the kickoff point for the next lateral at 7,550'. The liner included the aluminum liner top billet which CTD uses to kickoff from, however the billet was unable to pass through the 3 -1/2" x 7" window (6409' — 6420'). At that time we POOH and removed the billet, and ran the liner to bottom, leaving the current liner top at 7,590'. Operations then proceeded to clean up the window with a milling assembly which became stuck • in the window at 6,411'. Since the BHA was fished/jarred out of the window the rig has been unable to exit the window. In an attempt to diagnose the problem with the window, a LIB was run, but unfortunately parted on bottom. The decision was then made to rig down and move off to 1E -12, and allow slickline to move over the well to further evaluate the situation. Further rig operations on this well with • CDR2 -AC were suspended and the rig was released Feb. 14 12pm. Current Operations: Diagnose the condition of the 3 -1/2" x 7" window (6409' — 6420') and or whipstock placement/orientation with non -rig operations. After diagnosis of the problem with the window, a future plan of action will be developed for the rig. Slickline • RIH w/ Brush; clean hole down to CTD tag depth of 6420' MD • RIH w/ PDS 1- 11/16" — 24 arm Caliper •. Run GLV's Produce to system E -line - RIHw/ Video (at a later date) 2/17/2010 3I -11 Post -CTD Procedure Page 1 of 1 1 31 -11 Suspended CTD Sidetrack - Status as of U 17- Feb•10 i Cameo TRMAXX -5E SSSV © 2212 MD (2.813" min ID, X- profile) �• 3 -1/2 ", 9.3# L -80 EUE 8rd -Mod Tubing to surface 16" 62# H -40 shoe @116'MD 3 -1/2" Camco MMG gas lift mandrels (5) © 2512, 3702', 4760', 5668', & 6074' 9 -5/8" 36# J -55 shoe © 3383' MD X' landing nipple @ 6123' MD (2.813" min ID) ~ Baker 3 -1/2" seal assembly 6131' - 6143' MD ill 1 f 80 -40 PBR at 6132' - 6145' I Baker KBH Anchor Seal Assy at 6145' MD miles Baker SAB 40 -32 packer @ 6146' MD MI 'X' landing nipple @ 6156' MD (2.813" min ID) pg g . t G y ; ., ...: - , :..i• Holes shot in 3 -1/2" straddle at -6408' -6413' & 6213' MD Ii ` 4P ;;, ;;; 13:0 Baker F1 permanent packer @ 6422' MD (e -line set) 10 `�:" - 80 : 'n ID) cemented in place WLEG @ 6438' MD FISH: 3-1/2" ' . monobore / /- rill whipstock at 6422' _== (TOWS) (L1 TD @ 9437' ( A2 • ..........,...-'.---''............„,..........„......../ I A sand perfs sand) A3: 6437' - 6454' — A2: 6457' - 6486' Top of 2 -3/8" slotted Al: 6494' - 6503' FISH: 3 -1/2" monobore liner - 7590' --` whipstock Depth unknown 7" 26# J -55 shoe © 6550' MD 31_11 o plan Ct■notoPhillip, . 1 North 0 6950 7450 South 6400 • I 1 I 7950 1 --- -T"—--- 1 8450 8950 3000 1 500 1 1 - • i 1 T i ! 1 [ 1 ----.--- J L1-02: KOP @ 7300' MD IMMEN111111•111111111 MIN 111111111111 ' 1000 1500 limmoto •■•••'"''''''''' 2000 muii■E t 2500 3000 6050 - - .. 6 1 ..c._.,_ -....., \ _ ----- ------ _—........i —______ __f_:, — — — ----;,aN■-•sogrF'4'4''''g,*,,,-a.r--gvrAmtFs,-- _ -- - - ____ 6' 50 --... \ _ _ , — - 5 - --e., ,_ . - - - 6200 \ _ - - - 1 /` ' _ i _ 3 \ x JO - 1 6250 — _ 0 A2 Target Paints < ‹.., • A3 Target Points 1 1 41( L1-01: KOP @ 7400' MD • ..1 Target Points -441( Distance in A2: 1920 feet Distance in A1: 1620 feet Distance in: 1680 feet 6300 0 Landing Point • 1 - 31-11 New Plan C • 0 1 1�ps L1 -02: KOP @ 7550' MD 60s0 .1aailt A 31 -11L1 Surveys ___ • • • • • ____ • P.Ira.n _L________________v__:__,__.. _ _J_ I__L_ L_1.J_ ____L_L_ _J_._. 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I 1\ ;ism edI)eptlk L1 -01: KOP @ 7290' MD NABOBS ALASKA Cl.),', 2140 0 4111 1 14:11, t b E SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS / 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION f ANCHORAGE, ALASKA 99501 -3539 / PHONE (907) 279 -1433 FAX (907) 276 -7542 Mr. J. Cawvey Alaska Wells Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 -0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, 3I -11L1 ConocoPhillips Alaska, Inc. Permit No: 209 -121 Surface Location: 147' FSL, 48' FEL, Sec. 36, T13N, R8E, UM Bottomhole Location: 2609' FSL, 2378' FEL, Sec. 6, T12N, R9E, UM Dear Mr. Cawvey: Enclosed is the approved application for permit to re -drill the above referenced development well. The permit is for a new wellbore segment of existing well KRU 31 -11, Permit No. 1890350, API No. 50- 029 - 21932 -00. Production should continue to be reported as a function of the original API number stated above. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659 -3607 (pager). Sincerely, z/ 1,14,e.,/,./14A._ Cathy '. Foerster Commissioner DATED this 7 day of October, 2009 cc: Department of Fish 85 Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. 1 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 1a. Type of Work: • 1b. Current Well Class: Exploratory ❑ Development Oil Ei . 1c. Specify if well is proposed for: Drill ❑ Re -drill IN Stratigraphic Test ❑ Service ❑ © s. Development Gas ❑ t . Coalbed Methane ❑ Gas Hydrates ❑ Re -entry II Multiple Zone' It" 01 Single Zone �V i. Shale Gas ❑ 2. Operator Name: i d. `t - 5. Bond: U Blanket U Single Well 11. Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59 - 52 - 180 , 31 - 11 L1 ,. 3. Address: 6. Proposed Depth: 12. Field /Pool(s): P.O. Box 100360 Anchorage, AK 99510 - 0360 MD: 9150' ' TVD: 6136' . Kuparuk River Field 4a. Location of Well (Govemmental Section): 7. Property Designation: Surface: 147 FSL, 48' FEL, Sec. 36, T13N, R8E, UM ' ADL 25523, 25631 ' Kuparuk River Oil Pool ' Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 1059' FNL, 1835' FEL, Sec. 6, T12N, R9E, UM 2559, 2564 11/1/2009 Total Depth: 9. Acres in Property: 14. Distance to 2609' FSL, 2378' FEL, Sec. 6, T12N, R9E, UM ' 2437 Nearest Property: 18560 • 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL: , 76 feet 15. Distance to Nearest Well Open Surface: x - 507830 • y - 6007088 ' Zone 4 KB Elevation above GL: 16.5 feet to Same Pool: 31 -13 , 1500 . 16. Deviated wells: Kickoff depth: 6407 • ft. 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 96° , deg Downhole: 4452 psig • Surface: 3804 psig - 18. Casing Program Specifications Setting Depth Quantity of Cement Size Top Bottom !� c. f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD RE(� vv Ttif l�igljta) 0 OCT // no 3" 2.375" 4.7# L -80 ST -L 1750' 7400' 6159' 9150' 6 ifrisita 01110131 Corpr ii s np 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Oper o s) ge Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) 6772' 6560' 6680' 6473' Casing Length Size Cement Volume MD TVD Conductor /Structural 116' 16" 250 sx CS II 116' 116' Surface 3348' 9 -5/8" 330 sx Class G, 3383' 3383' Intermediate 544 sx AS 111, 175 sx AS 1 Production 6728' 7" 250 sx Class G, 175 sx AS 1 6762' 6550' Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 6437'- 6454', 6457'- 6486', 6494' -6503' 6245'- 6261', 6264'- 6291', 6298' -6306' 20. Attachments: Filing Fee ❑ BOP Sketch 0 Drilling Program Q Time v. Depth Plot ❑ Shallow Hazard Analysis ❑ Property Plat ❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program 0 20 AAC 25.050 requirements 5 21. Verbal Approval: Commission Representative: Date: /7 22. I hereby certify that the foregoing is true and correct. Contact James Ohlinger @ 265 - 1102 0. Printed Name J. Cawvey > Title Alaska Wells Manager v y9 Signature Phone "75 "c� Date f ®f v/ 9 r .,,,,,,-- - 2--' 4, / j Commission Use Only Permit to Drill API Nu Permit Approva See cover letter '7 ,� /� / / 7� ///��� requirements for other re Number: 2_ 8 t z /V 50- (s ° 2 / / 32 (cK ° I Date: 0D / Q y I q Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coaled me ane, gas hydrates, or gas contained in shales: X L/5 ps` Sof AS' ' /- Samples req'd: Yes ❑ ' No Mud log req'd: Yes El No [v] Other: 7 r ,.. � H2S measures: Yes [+ No ❑ Directional svy req'd: Yes [ No ❑ , ,25410 /° si- Ann 1 cs f C h1 o,q c_ - rz et. c- L4 et_ dL s' t 3T - 1 ( (PTI) 117-63s re t� / AP' ROVED BY THE COMMISSION DAME: M 2 ? • , •t r ■ . � i) , 1 / . ,, COMMISSIONER w Form 10 -401 (Revised 1/2009) / ../.3.09,0 Subm in Duplica L • • Permit to Drill Summary of Operations KRU 31-11L1, 3I-11L1-01, & 31-11L1-02 Laterals Coiled Tubing Drilling Overview: Well 31 -11 is a 3 %" tubing x 7" casing producer in the Kuparuk A -sand. Three proposed CTD laterals will access reserves in an unswept area to the south. The existing A -Sand perfs in 31 -11 will be unaffected by these CTD laterals – the kickoff point will be in the 3'/z" straddle portion above the current completion. The 31-11L1 lateral will exit the 3W tubing and 7" casing at 6407' MD and will target the A2 sand south of the • existing well with a 2743' lateral. The hole will be completed with a 2%" slotted liner to the TD of 9150' MD with a liner top aluminum billet at 7400' MD. The 3I-11L1-01 lateral will kick off from the aluminum billet at 7400' MD and will target the Al sand south of the existing well with an 1800' lateral. The hole will be completed with a 2%" slotted liner to the TD of 9200' MD with a liner top aluminum billet at 7300' MD. The 3I-11L1-02 lateral will kick off from the aluminum billet at 7300' MD and will target the A3 sand south of the existing well with an 1800' lateral. The hole will be completed with a 2 %" slotted liner to the TD of 9100' MD with the final liner top located just inside the 3 tubing at 6385' MD. Operational Outline Pre -Rig Work 1. Positive pressure and drawdown tests on MV, SV, and SSSV. 2. DGLV's, load tbg & IA. MIT - IA. MIT -OA. 3. Shoot tubing punches in 3'h' tubing at 6411' and 6213' MD. 4. Set plug between tubing punches. Pump down tubing through tubing punches to confirm communication across the 3'/2" x 7" annulus. 5. RU a -line. Set composite bridge plug at 6417' MD (inside seal assembly). (6."1164 6. RU CTU. Lay in cement plug. Objective is to anchor the 3'/2" tubing inside the 7" casing at the 31 -11 sidetrack point. 7. RU slickline. Tag cement top. r al 8. Drill out cement and composite bridge plug. 9. Caliper survey 3'/z° tubing where cement was drilled out. Run dummy whipstock on slickline. 10. RU a -line. Set 3'/" monobore, flow -by whipstock at 6407' MD. 11. Prep site for Nabors CDR2 -AC. Rig Work • 1. MIRU Nabors CDR2 -AC rig using 2" coil tubing. NU 7- 1/16" BOPE, test. 2. 31-11L1 Lateral (A2 Sand) is ' TD a. Mill 2.74" 2- string window with high -side orientation at 6407' MD (n b. Drill 2.70" x 3" bi- center lateral in the A2 sand to TD of 9150' MD. c. Kill well. Run 2 %" slotted liner with an aluminum liner -top billet from TD up to 7400' 3. 31- 11L1 -01 Lateral (Al Sand) a. Kick off of the aluminum billet at 7400' MD b. Drill 2.70" x 3" bi- center lateral in the Al sand to TD of 9200' MD. c. Kill well. Run 2%" slotted liner with an aluminum liner -top billet from TD up to 7300' 4. 31- 11L1 -02 Lateral (A3 Sand) a. Kick off of the aluminum billet at 7300' MD b. Drill 2.70" x 3" bi- center lateral in the A3 sand to TD of 9100' MD. c. Kill well. Run 2 %" slotted liner from TD up to 6385' MD, into the 3'/" tubing 5. Freeze protect. ND BOPE. RDMO Nabors CRD2 -AC. Page 1 of 5 9/29/2009 ORIGINAL • • Permit to Drill Summary of Operations Cont. KRU 3I -11 L1, 31-1 1 L1 -01, and 31-1 1 L1 -02 Post -Rig Work 1. Install GLV's 2. Obtain SBHP 3. Produce to system Mud Program: • Will use chloride -based Biozan brine (8.6 ppg) for milling operations, and chloride -based Flo -Pro mud • ( -10.0 ppg) for drilling operations. There is a SSSV installed in 3I -11, so we should not have to kill the well to deploy 2%" slotted liner. �^ Disposal: • No annular injection on this well. • Class II liquids to KRU 1R Pad Class II disposal well • Class II drill solids to Grind & Inject at PBU Drill site 4 • Class I wastes will go to Pad 3 for disposal. Casing Program: • 3I - 11L1: 2% ", 4.7 #, L -80, ST -L slotted liner from 7400' MD to 9150' MD • 3I- 11L1 -01: 2% ", 4.7 #, L -80, ST -L slotted /solid liner from 7300' MD to 9200' MD • 3I- 11L1 -02: 2% ", 4.7 #, L -80, ST -L slotted /solid liner from 6397' MD to 9100' MD Existing Casing/Liner Information Surface: 9% ", J -55, 36 ppf Burst 3520 psi; Collapse 2020 psi Production: 7 ", J -55, 26 ppf Burst 4980 psi; Collapse 4320 psi Well Control: • Two well bore volumes (-222 bbl) of KWF will be available to the rig during drilling operations. The kill . weight fluid may or may not be stored onsite, but if it is stored offsite it will be in the Kuparuk Field within a short drive to the rig. • BOP diagram is attached for operations with 2" coil tubing. pSQ • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 si and to 4500 si. Maximum _potential surface pressure in 3I -11 is 3804 psi assuming a gas gra tent to surface and maximum potential formation pressure. Maximum potential formation pressure is based on the highest recent measured bottom hole pressure in the vicinity, which is 4452 psi at 6244 TVD in offset injector 3I -13 measured August 2009. Well 31-13 had been shut -in several months when this survey was taken. • The annular preventer will be tested to 250 psi and 2500 psi. Directional: • See attached directional plans: 1. 3I -11L1, plan #6 2. 3I- 11L1 -01, plan #3 3. 3I- 11L1 -02, plan #3 • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • All 31-11 CTD laterals: 18,560' to property line, 1500' from well 3I -13 Logging • MWD directional, resistivity, and gamma ray will be run over the entire open hole section. Page 2 of 5 9/29/2009 ORIGINAL • Permit to Drill Summary of Operations Cont. KRU 31-11L1, 3I-11L1-01, and 3I-11L1-02 Reservoir Pressure • The most recent static BHP survey in well 3I -11 was taken May 2009, which measured reservoir pressure of 4255 psi at 6469'MD, 6275' TVD, corresponding to 13.0 ppg EMW. Expect to encounter increasing pressure as the laterals are drilled away from the mother well due to anticipated interaction with injection well 31 -13. 3I -13 has been shut in since September 2008 to allow the area to de- pressurize. The most recent pressure survey in 31 -13 showed 4452 psi at 6244 TVD (13.7 ppg EMW) as of August 2009. Hazards • Lost circulation is not expected to be particularly troublesome. Expect to encounter increasing pressure as the laterals are drilled away from the mother well. • Over - pressured zones are a potential hazard in 31 -11. Even with 10.0 ppg mud, choke pressure will have to be maintained while drilling, both for maintaining well control and borehole stability. Use of the SSSV to deploy slotted liner should eliminate the need to spot heavy kill weight fluid, but if the SSSV fails then completion fluids in excess of 13.0 ppg will be needed to kill the well. • Shale stability is a potential problem, particularly in the build section where the A5 sand will be encountered. Will mitigate potential sloughing problems by cutting this interval at less than 60° hole angle, and by holding a constant ±13.2 ppg EMW on the formation throughout drilling operations. • Well 31 -11 has 150 ppm H as measured on 6/22/09. Well 31 -12 is located 25' to the left side and 31 -10 is 25' to the right side of the 31 -11 surface location. The 31 -12 has no measured H since it is an injector. The H measured in 31 -10 is 120 ppm (1/2/09). The maximum H level on the pad is 160 ppm from wells 31 -04 (12/17/08) and 31 -17 (1/10/09). All H monitoring equipment will be operational. Managed Pressure Drilling Managed pressure drilling (MPD) techniques will be employed to provide constant bottom hole pressure by using 10.0 ppg drilling fluid in combination with annular friction losses and applied surface pressure. Constant BHP will be utilized to reduce pressure fluctuations to help with hole stability. Applying annular friction and choke pressure also allow use of less expensive drilling fluid and minimizes fluid losses and /or fracturing at the end of the long well bores. A hydraulic choke for regulating surface pressure is installed between the BOPE choke manifold and the mud pits, and is independent of the BOPE choke. Using this technique will require deployment of the BHA under trapped wellhead pressure. Pressure deployment of the 2%" BHA will be accomplished utilizing the 2%" pipe rams and slip rams. The annular preventer will act as a secondary containment during deployment and not as a stripper. Well 3I -11 has a SSSV, so the well should not have to be killed prior to running slotted liner. Operating parameters and fluid densities will be adjusted based on real -time bottom hole pressure measurements while drilling and shale behavior. The following scenario is expected at TD: • Estimated reservoir pressure: 4203 psi at 6407' MD (6217' TVD), or 13.0 ppe EMW. • Expected annular friction losses while circulating: 577 psi (assuming friction of 90 psi /1000 ft due to the 3 tubing) • Planned mud density of 10.0 ppg equates to 3233 psi hydrostatic bottom hole pressure at 6217' TVD • • While circulating 10.0 ppg mud, bottom hole circulating pressure is estimated to be 3810 psi or 11.8 ppg EMW without holding any additional surface pressure. This alone is insufficient to overbalance expected formation pressure in 3I -11, so —450 psi choke pressure will be required while drilling to maintain overbalance. If increased formation pressure is encountered, mud weight or choke pressure will be increased to maintain overbalance. • When circulation is stopped, 1000 psi of surface pressure shall have to be applied to maintain the same borehole pressure as during drilling operations. Page 3 of 5 9/29/2009 ORIGINAL 31 -11 Proposed CTD Sidetrack Updated: 24- Sep -09 Camco TRMAXX -5E SSSV @ 2212 MD (2.813" min ID, X- profile) - 3 -1/2 ", 9.3# L -80 EUE 8rd -Mod Tubing to surface 16" 62# H -40 shoe @ 116' MD • 3 -1/2" Camco MMG gas lift mandrels (5) @ - 2512', 3702', 4760', 5668', & 6074' 9 -5/8" 36# J -55 shoe @ 3383' MD -alai. I■ ■ 1. X' landing nipple @ 6123' MD (2.813" min ID) I IM I Baker 3 -1/2" seal assembly 6131' - 6143' MD IIII 80-40 PBR at 6132' - 6145' Baker KBH Anchor Seal Assy at 6145' MD Baker SAB 40 -32 packer @ 6146' MD C) M� 'X' landing nipple @ 6156' MD (2.813" min ID) 2 -3/8" liner top at -6390' MD 3-117 flow -by Holes shot in 3 -1/2" straddle at -6411' & 6213' MD monobore whipstock at 6407' MD -, • Baker Fl permanent packer @ 6422' MD (e line set) " 3-1/2" - 80 -40 Sealbore extension (6425'- 6430') D' landing nipple @ 6433' MD (2.750" min ID) 9100' " straddle I i cemented in place L1 -02 TD @ (wp03. A3 sand) - WLEG @ 6438' MD / �i /� -/ A sand perfs / �/ _...4 L TD @ 9150' -- - (wp06. A2 sand) A3: 643T - 6454' -- A2: 6457' - 6486' .r--....._ Al: 6494' - 6503' _ _ �---..._ .= lir ..--____ ---....... 2 -3/8" slotted pipe Aluminum billets @ 7400' MD L1 -01 TD @ 9200' 7" 26# J -55 shoe and 7300 MD (WP03) (wp03, Al sand) @ 6550' MD KUP 0 31 -11 ConocoPhillIps , Well Attributes Max Angle & MD TD 8�'T ' - - i Wellbore APIAIWI Field Name Well Status Ind (°) MD (ftKB) Act Btm (ftKB) Alaska, Inc. 500292193200 KUPARUK RIVER UNIT PROD 24.02 5,300.00 6,772.0 Loroovn,aips Comment H2S (ppm) Date Annotation End Date KB -Ord (R) Rig Release Date SSSV: TRDP 160 2/5/2008 Last WO: 6/1/2009 35.91 4/4/1989 Well Conti,: -31 -11 6/11/20097: 48: 14 AM Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod By End Date Last Tag: SLM 6,516.0 6/6/2009 Rev Reason: Workover, GLV C /O, Tag _ Imosbor 6/10/2009 Casing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd r ! CONDUCTOR 16 15.062 0.0 116.0 116.0 62.50 H - 40 HANGER. 31 ) z- Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 95/8 8.765 35.0 3,383.4 3,383.3 36.00 J -55 Casing Description String 0... String ID ... Top (RKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd r PRODUCTION 7 6.151 33.0 6,761.5 6,550.2 26.00 J -55 Tubing Strings - -- - Tubing Description String 0... String ID ... Top (RKB) Set Depth (f... Set Depth (TVD)... String Wt... String ... String Top Thrd TUBING - Upper 3 1/2 2.992 31.0 6,143.0 5,974.1 9.30 L -80 EUE CONDUCTOR, Completion Details 0 -116 Top Depth (ND) Top loci - Top (ftKB) (RKB) ( °) Item Description Comment FMC 6" x 31/2" Gen IV Tubing H ID (in) _ _ _ _ 31.0 31.0 0.02 HANGER anger w / pup 2.992 000V. 2.212 { o + 2,212.3 2,212.3 0.17 SSSV Cameo 3 1/7 x 2.813"'X' Profile TRMAXX -5E SCSSV "'LOCKED OPEN 2.813 w /6200 psi on control line" 6,123.0 5,955.7 23.60 NIPPLE Haliburton 3 1/2" x 2.813" 'X' Nipple 2.813 6,131.0 5,963.1 23.57 SEAL ASSY Baker 80-40 Seal Assembly (2' Space out) 3.000 T Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd GAS LIFT, q [ �� TUBING -Mid 31/2 2.992 6,133.6 6,429.0 6,238.1 9.30 L-80 EUE 2.512 E Section - Completion Details Top Depth SURFACE, )TVD) Top Ind 35 -3,383 Top (ftKB) (ftKB) (°) Item Description Comment ID (in) __ 6,133.6 5,965.5 23.57 PBR Baker 80-40 PBR 3.000 6,147.0 5,977.7 23.53 SEAL ASSY Baker KBH -22 80 -DA-40 Anchor Seal Assy 3.000 GAS LIFT. 3.702 C, 6,147.9 5,978.6 23.53 PACKER Baker 84-SAB-40x32 Retainer Prod. Packer 3.250 6,152.8 5,983.1 23.51 XO Reducing X-over Sub, 4 1/2' LTC pin x 3 1/2' EUE pin 3.010 �- - 6,157.8 5,987.6 23.50 NIPPLE Haliburton 2.813" 'X' Nipple 2.813 _ -, 6,421.3 6,231.0 22.77 SEAL ASSY Baker 80 GBH - 22 Seal Assy w/LOcator 3.000 Tubing Description g 0... 'String ID ... Top (ftKB) Set Depth (f... Depth (TVD) ... String Wt... String ... String Top Thrd GAS LIFT, PACKER ASSY 'String Str 4.000 I 6,422.1 6,438.0 'Set D 6,246.3 I ACME 4,760 Completion Details Top Depth (TVD) Top Incl Top (ftKB) (ftKB) ( °) Some Description Comment ID (in) 6,422.1 6,231.8 22.76 PACKER Baker 85- 40'F1' Permanent Production Packer 4.650 GAS LIFT, 6,425.4 6,234.8 22.69 SBE Baker 80-40 SBE (5' Long) w/ XO Sub 4.000 5,668 6,429.9 6,238.8 22.59 XO - Reducing X -Over Sub 5" BTC x 3.5" EUE 6,433.4 6,242.1 22.52 NIPPLE 3.000 - Camco312° "'D'Nipple 2.750 6,437.1 6,245.4 22.44 SOS Shearout Sub w/ WLEG 3.000 GAS LIFT, c Perforations & Slots 6,074 Shot III Top (TVD) Otto (TVD) Dens Top (MB) Btm MKS) (ftKB) (RKB) Zone Date (OD- Type Comment 6,437 6,454 6,245.4 6,261.0 A -3, 31 -11 3/6/1990 8.0 IPERF 2 1/8" Dyna Strip, 60 deg ph -- 6,457 6,486 6,263.7 6,290.6 A -2, 31 -11 5/18/1989 4.0 IPERF 4.5 "HSD Csg Gun, 90deg ph In NIPPLE. 6.123 6,494 6,503 6,298.0 6,305.8 A -1, 31 -11 3/6/1990 8.0 IPERF 21/8" Dyna Strip, 60 deg ph Notes: General & Safety End Date Annotation SEAL ASSY, _ 6/10/2009 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 6,131 PBR. 6.134 SEAL ASSY, 6,147 �'" PACKER, 6,148 F 1 NIPPLE, 6,158 " ill 1 PACKER, 8,4227 SEAL ASSY, 8,421 SBE, 6,425 Mandrel Details Top Depth ! Top Port (TVD) Intl OD Valve Latch Size TRO Run Stn Top (ftKB) (RKB) ( °) Make Model (in) Sent Type Type (in) (psi) Run Date Com... MP 1 2,511.6 2,511.6 0.09 Cameo MMG 1 12 GAS LIFT GLV RK 0.188 1,265.0 6/52009 NIPPLE, 6,433 2 3,702.1 3,701.9 3.84 Cameo MMG 1 1/2 GAS LIFT GLV RK 0.188 1,261.0 6/52009 3 4,760.5 4,706.8 23.38 Cameo MMG 1 1/2 GAS LIFT GLV RK 0.188 1,254.0 6/5/2009 4 5,667.8 5,538.4 23.61 Cameo MMG 1 12 GAS LIFT GLV RK 0.188 1,245.0 6/5/2009 505, 6,437 ® 5 6,074.0 5,910.7 23.36 Cameo MMG 1 1/2 GAS LIFT OV RK 0.188 0.0 6/5/2009 IPERF, 6,437 -6,454 IPERF, ■ ■ 6,4576,486 PERF, III II 8.494 ERE. PRODUCTION, 33 6,76, ORIGINAL • • ConocoPhilli s 1� ,„„:„ Alaska ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 31 Pad 31 -11 31-1 1L1 Plan: Plan 6, 31-1 1 L1 Standard Planning Report 02 October, 2009 r I BAKER E HUGHES ORIGINAL • • I►' • ConocoPhillips ' COflOCOPh d • Planning Report BAKER Alaska HUGHES Dat l�s9e' EDM Alaska Prod v16 L l Co O dlna R efere ce Well 31 -11! ConocoPh Inc. ; T�VD woe Mean Sea Level Kuparuk River Unit `Ml) Reference 31 -11 @ 76.00t (31_11) Kuparuk 31 Pad efen nce: True Y1 etl 31 -11 survey Ca lculation Minimum Curvature fltara* , 31-11L1 Plan 6, 31 -11L1 Me su d TYDBelow e � I � M ap` .; E pth „ inclination . Azi , 6,400.00 21.98 210.19 6,134.60 - 845.69 - 445.06 955.65 0.00 0.00 6,006,242.09 507,386.10 TIP 31 6,407.00 • 21.92 210.20 6,141.09 - 847.95 - 446.38 958.27 0.86 176.44 6,006,239.82 507,384.79 KOP 6,422.00 24.92 210.20 6,154.86 - 853.10 - 449.38 964.22 20.00 0.00 6,006,234.67 507,381.79 End of 20 deg /100 ftDLS 6,500.00 57.68 210.20 6,212.66 - 896.99 - 474.92 1,014.96 42.00 0.00 6,006,190.76 507,356.30 6,588.86 95.00 210.20 6,233.28 - 970.31 - 517.59 1,099.71 42.00 0.00 6,006,117.41 507,313.71 4 6,600.00 95.06 214.90 6,232.30 - 979.66 - 523.56 1,110.77 42.00 89.00 6,006,108.05 507,307.75 6,633.86 95.05 229.17 6,229.30 - 1,004.64 - 546.08 1,143.36 42.00 89.41 6,006,083.04 507,285.25 End of 42 deg 1100'ft DLS 6,700.00 95.14 237.14 6,223.41 - 1,044.11 - 598.76 1,202.83 12.00 89.00 6,006,043.52 507,232.62 6,783.86 95.11 247.25 6,215.89 - 1,083.02 - 672.54 1,271.62 12.00 89.71 6,006,004.54 507,158.89 6 6,800.00 95.21 249.19 6,214.44 - 1,088.99 - 687.47 1,283.85 12.00 87.00 6,005,998.56 507,143.97 6,900.00 95.69 261.23 6,204.91 - 1,114.36 - 783.54 1,351.04 12.00 87.17 6,005,973.09 507,047.94 7,000.00 95.91 273.29 6,194.77 - 1,119.10 - 882.73 1,401.43 12.00 88.32 6,005,968.24 506,948.76 7,033.86 95.93 277.38 6,191.28 - 1,115.97 - 916.25 1,414.28 12.00 89.55 6,005,971.34 506,915.24 7 7,100.00 95.87 269.40 6,184.47 - 1,112.09 - 981.88 1,441.40 12.00 -90.00 6,005,975.15 506,849.62 7,200.00 95.57 257.34 6,174.46 - 1,123.56 - 1,080.53 1,497.49 12.00 -90.82 6,005,963.58 506,750.99 7,283.86 95.13 247.24 6,166.62 - 1,148.92 - 1,159.96 1,556.93 12.00 -92.03 6,005,938.14 506,671.60 8 7,300.00 94.73 245.34 6,165.24 - 1,155.39 - 1,174.68 1,569.51 12.00 - 102.00 6,005,931.66 506,656.88 7,400.00 92.12 233.61 6,159.25 - 1,206.00 - 1,260.50 1,654.27 12.00 - 102.16 6,005,880.95 506,571.12 7,418.86 91.61 231.40 6,158.64 - 1,217.48 - 1,275.46 1,671.39 12.00 - 102.87 6,005,869.47 506,556.18 9 7,500.00 91.93 221.66 6,156.13 - 1,273.20 - 1,334.25 1,748.08 12.00 -88.00 6,005,813.68 506,497.45 7,600.00 92.24 209.66 6,152.48 - 1,354.25 - 1,392.41 1,846.88 12.00 -88.30 6,005,732.59 506,439.39 7,700.00 92.45 197.65 6,148.38 - 1,445.60 - 1,432.42 1,946.36 12.00 -88.74 6,005,641.20 506,399.47 7,800.00 92.56 185.64 6,143.99 - 1,543.27 - 1,452.56 2,042.17 12.00 -89.23 6,005,543.53 506,379.44 7,898.86 92.55 173.77 6,139.57 - 1,641.85 - 1,452.05 2,129.17 12.00 -89.76 6,005,444.96 506,380.05 10 7,900.00 92.56 173.90 6,139.52 - 1,642.98 - 1,451.92 2,130.11 12.00 86.00 6,005,443.82 506,380.17 8,000.00 93.33 185.89 6,134.36 - 1,742.66 - 1,451.75 2,218.24 12.00 86.01 6,005,344.15 506,380.46 8,023.86 93.50 188.76 6,132.94 - 1,766.28 - 1,454.78 2,240.56 12.00 86.63 6,005,320.53 506,377.45 11 8,100.00 92.66 197.87 6,128.84 - 1,840.19 - 1,472.28 2,314.11 12.00 95.00 6,005,246.61 506,360.03 8,200.00 91.46 209.82 6,125.22 - 1,931.43 - 1,512.60 2,413.63 12.00 95.49 6,005,155.34 506,319.81 8,273.86 90.54 218.63 6,123.93 - 1,992.43 - 1,554.10 2,486.93 12.00 95.92 6,005,094.30 506,278.38 12 8,300.00 90.54 215.50 6,123.69 - 2,013.28 - 1,569.85 2,512.73 12.00 -90.00 6,005,073.43 506,262.65 8,400.00 90.52 203.50 6,122.76 - 2,100.16 - 1,619.00 2,612.49 12.00 -90.03 6,004,986.51 506,213.60 8,500.00 90.48 191.50 6,121.89 - 2,195.35 - 1,649.00 2,710.71 12.00 -90.14 6,004,891.30 506,183.70 8,600.00 90.42 179.50 6,121.11 - 2,294.71 - 1,658.56 2,803.09 12.00 -90.24 6,004,791.94 506,174.24 8,608.86 90.41 178.43 6,121.04 - 2,303.57 - 1,658.40 2,810.85 12.00 -90.34 6,004,783.09 506,174.41 13f 8,700.00 90.21 189.37 6,120.55 - 2,394.36 - 1,664.59 2,894.08 12.00 91.00 6,004,692.30 506,168.32 8,733.86 90.14 193.43 6,120.44 - 2,427.54 - 1,671.28 2,926.56 12.00 91.06 6,004,659.11 506,161.66 14 8,800.00 88.84 201.26 6,121.03 - 2,490.62 - 1,690.98 2,991.56 12.00 99.40 6,004,596.01 506,142.03 10/2/2009 2:49:04PM Page 3 COMPASS 2003.16 Build 69 ORIG%NAL • • r-' ConocoPhillips Conoco Phillips Planning Report BAKER Database EDM Alaska Prod v16 =LeCeit ordinate Ft tfcre Well 31 -11 Co parry ': . ConocoPhillips(Alaska)Inc. 11fDReferenda Mean Level ro act Kuparuk River Unit MD Riliference: ; ` 31 -11 @ 76.00ft (31 -11) Site Kuparuk 31 Pad Reference: True Well 31 -11 unrey Calculation Me d Minimum Curvatu 1000140,1- Plan 6, 31-11L1 Pia avert Su ey Measttr �d ° fVD Below Vei cai g leg ittclina on A zimuth °Sy m +Nf S ` ` '44/ W Rate irit l ►tt s1 1 ° O, m t tit) )` . (It) # ( t 8,883.86 87.24 211.20 6,123.91 - 2,565.70 - 1,727.98 3,075.23 12.00 99.33 6,004,520.90 506,105.12 15 8,900.00 87.24 209.26 6,124.69 - 2,579.63 - 1,736.10 3,091.33 12.00 -90.00 6,004,506.96 506,097.02 9,000.00 87.32 197.25 6,129.45 - 2,671.24 - 1,775.46 3,190.73 12.00 -89.91 6,004,415.33 506,057.75 9,100.00 87.52 185.24 6,133.97 - 2,769.04 - 1,794.90 3,286.33 12.00 -89.33 6,004,317.52 506,038.41 9,150.00 87.66 179.23 6,136.08 - 2,818.93 - 1,796.85 3,331.39 12.00 -88.79 6,004,267.63 506,036.52 TD at 9150.00 T'a'rgets, Tat Mama ttltttnlsd tats Dip Angle Dip ©lr TYD +M/-S , +EI W. Northing E , ,, ( °) CI 3 ... (f ft) (ft) ( r l o u de 3I-11L1 t4.6 0.00 0.00 6,120.00 - 2,435.09 - 1,662.75 6,004,651.57 506,170.20 70° 25 26.170 N 149° 56' 59.009 W - plan misses target center by 10.11 ft at 8738.52ft MD (6120.44 TVD, - 2432.07 N, - 1672.39 E) - Point 31-11L1 fault 2 0.00 0.00 0.00 - 1,499.67 - 1,038.69 6,005,587.55 506,793.21 70° 25' 35.371 N 149° 56' 40.709 W - plan misses target center by 6152.81ft at 8023.86ft MD (6132.94 TVD, - 1766.28 N, - 1454.78 E) - Polygon Point 1 0.00 - 1,499.67 - 1,038.69 6,005,587.55 506,793.21 Point 2 0.00 - 705.96 - 664.86 6,006,381.58 507,166.17 Point 3 0.00 415.07 - 583.73 6,007,502.58 507,246.12 Point 4 0.00 - 705.96 - 664.86 6,006,381.58 507,166.17 31-11L1 fault 3 0.00 0.00 0.00 - 2,354.42 - 1,338.63 6,004,732.57 506,494.20 70° 25' 26.964 N 149° 56' 49.503 W - plan misses target center by 6129.15ft at 8671.33ft MD (6120.67 TVD, - 2365.95 N, - 1660.78 E) - Polygon Point 1 0.00 - 2,354.42 - 1,338.63 6,004,732.57 506,494.20 Point2 0.00 - 2,275.07 - 1,684.59 6,004,811.55 506,148.19 Point 3 0.00 - 2,138.47 - 2,272.51 6,004,947.52 505,560.19 Point 4 0.00 - 2,275.07 - 1,684.59 6,004,811.55 506,148.19 31-11L1 fault 1 0.00 0.00 0.00 - 809.13 - 546.91 6,006,278.54 507,284.22 70° 25' 42.163 N 149° 56' 26.285 W - plan misses target center by 6135.56ft at 6400.00ft MD (6134.60 TVD, - 845.69 N, - 445.06 E) - Polygon Point 1 0.00 - 809.13 - 546.91 6,006,278.54 507,284.22 Point2 0.00 - 1,203.04 - 673.32 6,005,884.53 507,158.24 3I-11L1 t1.6 0.00 0.00 6,134.00 - 845.24 - 444.94 6,006,242.54 507,386.22 70° 25' 41.808 N 149° 56' 23.294 W - plan hits target center - Point 31-11L1 t5.6 0.00 0.00 6,136.00 - 2,804.97 - 1,808.16 6,004,281.58 506,025.20 70° 25' 22.532 N 149° 57' 3.271 W - plan misses target center by 11.34ft at 9136.49ft MD (6135.52 TVD, - 2805.43 N, - 1796.84 E) - Point 31-11L1 t2.6 0.00 0.00 6,233.00 - 981.17 - 523.09 6,006,106.54 507,308.22 70° 25' 40.471 N 149° 56' 25.586 W - plan misses target center by 1.48ft at 6600.74ft MD (6232.23 TVD, - 980.27 N, - 523.99 E) - Point 31 -11L1 t3.6 0.00 0.00 6,213.00 - 2,082.09 - 687.28 6,005,005.56 507,145.20 70° 25' 29.643 N 149° 56' 30.400 W - plan misses target center by 825.72ft at 8100.00ft MD (6128.84 TVD, - 1840.19 N, - 1472.28 E) - Point 10/2/2009 2:49:04PM Page 4 COMPASS 2003.16 Build 69 OR! G I N A L • S ConocoPhillips rni 03MCOPhillitIS Planning Report BAKER Alaska HUGHES 13afabase, . EDM Alaska Prod v16 Local Co- ordinate Ply Well 31 -11 ' Companyk •ConocoPhillips(Alaska) Inc. '7W_ rertce Mean Sea Level Kuparuk River Unit MD � 5ertce 31 -11 © 76.00ft (31 -11) Kuparuk 31 Pad North Reference" True 31 -11 s urvey Calculation Method l Minimum Curvature `WItetlt = 3I -11L1 Plan 6, 31-11L1 Poi Measured La ing Hole depth Depth Diameter l�nt�r �, ? i � t ar ( f" 9,150.00 6,136.08 2 -3/8" 2 -3/8 3 Plan Atrnotatlons Me a ed Vertical Local Coordinates eft Depth ; ll-S 1 l =ltlf f) { l fit) Comilient 6,400.00 6,134.60 - 845.69 -445.06 TIP 31 -11 6,407.00 6,141.09 - 847.95 - 446.38 KOP 6,422.00 6,154.86 - 853.10 - 449.38 End of 20 deg / 100 ft DLS 6,588.86 6,233.28 - 970.31 - 517.59 4 6,633.86 6,229.30 - 1,004.64 - 546.08 End of 42 deg / 100 ft DLS 6,783.86 6,215.89 - 1,083.02 - 672.54 6 7,033.86 6,191.28 - 1,115.97 - 916.25 7 7,283.86 6,166.62 - 1,148.92 - 1,159.96 8 7,418.86 6,158.64 - 1,217.48 - 1,275.46 9 7,898.86 6,139.57 - 1,641.85 - 1,452.05 10 8,023.86 6,132.94 - 1,766.28 - 1,454.78 11 8,273.86 6,123.93 - 1,992.43 - 1,554.10 12 8,608.86 6,121.04 - 2,303.57 - 1,658.40 13 8,733.86 6,120.44 - 2,427.54 - 1,671.28 14 8,883.86 6,123.91 - 2,565.70 - 1,727.98 15 9,150.00 6,136.08 - 2,818.93 - 1,796.85 TD at 9150.00 10/2/2009 2:49:04PM Page 5 COMPASS 2003.16 Build 69 '► IL aM ap*No oRo,m WELLBORE DETAILS: 31 -11L1 REFERENCEINFOItuATpN IC all Project: Kuparuk River Unit uea�eaeaam:l7�a Site: k3lPad :57 Field 500292193260 CoadinAe () Reference: 00-5131- 11, True NaiM BAKER W 31-11 ell: 31 -11 soengh0:5rf56.7mT Vetkal (1V0) Reference: Mean Sea Level COf1000PF1�� Wellbore:3111L1 ppP ale � 8/° Parent Wellbore: 31-11 Measured Depth Reference:311 @70.000(31 -11) HUGHES \..Vg iVWrg Pla n: Plan 6,31 -11L1 31- 11131 -11L1 o0 I 191 r bad.eo°LU00s Tie on MD: 6400.00 Cakulalion Method: MnimumCwAure 750 WELL DETAILS: 31-11 251 1.....11111111111111111111111111 Ground Level: 0.00 411S +E/ -W N080ing Easting Latittude Longitude 0101 0 111111111111••111111111111111111111111111111111 111111111111••111111111111111111111111111111111 111111111111••111111111111111111111111111111111 0.00 0.00 6007088.16 507830.23 70° 25' 50.121 N 149° 56' 10.241 1W W SECTION DETAILS ANNOTATIONS 25 1111111111 ■11■■■111■VA 1111111111 Sec MD Inc Azi S8TVD +N/S +E / -W DLeg TFace VSec Target Amota1 111111 ■111111 ■1111111 ■■11 1 6400.00 21.98 210.19 6134.60 -845.69 - 445.06 0.00 0.00 955.65 TIP3I -11 2 6407.00 21.92 210.20 6141.09 -847.95 -446.38 0.86 176.44 958.27 501 ■ ■ ■■ ■11■ ■ii■'i 3 642200 24.92 210.20 61544.86 -85110 -449.38 End 49.38 20.00 0.00 964.22 Endof3deglt00ttDLS 4 6588.86 95.00 210.20 6233.28 - 970.31 -517.59 42.00 0.00 1099.71 4 -751 5 663386 95.05 229.17 6229.30 - 1004.64 - 546.08 42.00 89.00 114136 End of 42 deg I100tt DLS as 6 678386 95.11 247.25 6215.89 - 1083.02 - 672.54 12.00 89.00 1271.62 6 0 -1111 niiimmitimiiiiimarammimmEn 7 7033.86 95.93 277.38 6191.28 - 1115.97 - 916.25 12.00 87.00 1414.28 7 a e. • 8 7283.86 95.13 247.24 6166.62 - 1148.92 - 1159.96 12.00 270.00 1556.93 8 n 1111 ■ ■ ■11■We��� 11.ii1 _ 1'i il■ 9 7818.86 91.61 231.40 6158.64 -1217.48 -1275.46 12.00 258.00 1671.39 9 v 125 1111111111....111M171/11 ��111111 10 7898.86 9255 5 17177 6139.57 -1641.85 -145205 12.00 272.00 2129.17 10 11 802186 93.50 188.76 613294 - 1766.28 - 1454.78 12.00 86.00 2240.56 11 .15 t ndof4 deg/ 11' r 12 860186 90.44 278.43 612104 -199243 - 1654.40 12.00 95.00 2486.93 12 11..11.1111.1111111.1111111.11111111111111111111111 13 8608.86 90.41 178.43 6121.04 -2303.57 - 1658.40 12.00 270.00 2810.85 13 14 8733.86 90.14 1.43 6120.44 -2427.54 -1671.28 12.00 91.00 2926.56 14 CD 15 9150.86 87.24 1 71 3 6123.91 -2565.70 -1727.98 12.00 79.40 333.39 15 2 111...111111.11111111111111.....11111 111...111111.11111111111111.....11111 16 9150.00 87.66 179.23 6136.08 -2818.93 -1796.85 12.00 270.00 3331.39 TD at 9150.00 -2251 1111■ ■ ■5.E11 ■■11 ■ ■■ ■1111■ G) -251 ■11■■ ■ ■11N ■1111■■■■■■■■ -2751 ■■■. r . ■ 3i-1 ■■■■■■■■■■ aC..� -311 ■■■■■■■- ■■■■■■■■■■ � / -3500 -3250 - 3000 -2750 -2500 -2250 -2000 -1750 -1500 -1250 -1000 -750 -500 -250 0 250 500 750 1000 1 ssaod West(- )/East( +) (250 ft/in) 5670 5760 5850 • O C L'' ' 5940 C a ) i 6030 31.11M -11L1 Q 3 TIP 31-11 1 . 73 �' 6120 , 1 P. - - - _ : , 12 13 14 15 5 5 2 6210 8� 1+ 1 �� 5 � -_'"�, 6 7 TDat915000 6300 �ndof90 deg /100ftL LS 4 6390 - . Erdof42deg /I1 Oft DLS 6480 31-11. "t -11 6570 360 450 540 630 720 810 900 990 1080 1170 1260 1350 1440 1530 1620 1710 1800 189(1 1980 2070 2160 2250 2340 2430 2520 2610 2700 2790 2880 2970 3060 3150 3240 3330 3420 3510 3600 3690 3781) 3870 Vertical Section at 207.76° (90 ft/in) ■ • Azimuths to Tne Norte WELLBORE DETAILS: 31 -11L1 REFERENCEINFORMA110N /" Project: Kuparuk River Unit MagneecNoM: nom , Site: Kuparuk 31 Pad Cocrdnate(RE) Reference: Wel 31 -11, Tee North magnetic Flea 500292193260 Well: 31 -11 S.V1,57366.7enT Vertical (ND) Reference: 31-11 @ 76008 (3411) BAKER W ellbore: 31 -11 L1 o pAMe:7a.ea• Section (VS) Reference: Sld • (0.00X, 0.00 ConocoRhillip5 me 11/1/200S Parent Wellbore: 31 -11 Meowed Depth Reference: 3411 @76.008(3411) Plan: Plan 6, 31 -11L1 (31- 11/31 -11 L1) MoaN 1)30,A2005 Tie on MD: 6400.00 HUGHES Alaska Calculation MininunCuvdlre (. \ 400 \� \ \ -500 i , ' Air , _700 \ 41 - D . ,un _ ..,.....,_ i „„, • loon % \ -1101 i1 - l 1 -11 i CD -1200 \\ -1300 1 / 33 = 31- 1;.31 -I. 1 , a ■ G) O -1500 ' } �- J I ,,,,........ ...., ,,, yr,, ,,,,• I \ Allill , 161X1 y = \ o -1700 I J -18(10 r ". O 1. 1 j 1 \\ , L� -2000 \ -2100 + \ -2200 -2300 I \ , I -2400 -2500 11-1 431.14 — — — — -2600 -2700 -2800 '� 6 31 - -11L 1 -2900 31- I5l+I -I; 31173f-17 31 -11 ©76.00ft (31 -11) 30q V . -2900 -2800 4118834600 -2500 -2400 -2300 -2200 -2100 -2000 -1900 -1800 -1700 -1600 -1500 -1400 -1300 -1200 -1100 -1000 -900 -800 -700 -600 -500 -400 -300 -200 -100 0 100 200 300 400 500 600 700 800 West( - )/East( +) (100 ft/in) • • ConocoPhillips Ufa P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 September 29, 2009 Commissioner- State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits an application for permits to drill three lateral sidetracks out of Kuparuk Well 31 -11 using the coiled tubing drilling rig, Nabors CDR2 -AC. Work is scheduled to begin on 31 -11 as early as November 2009. The CTD objective is to drill three lateral sidetracks (31 -11 L1, 31-11L1-01, 3I-11L1-02) targeting the Al, A2 & A3 sands to access reserves from currently undrained areas to the south. Nabors CDR2 -AC will kickoff at a depth of 6407' MD (in the C4 sand). This kickoff location will require a window through the 3 -1/2" tubing and the 7" casing using a 2.74" mill. A retrievable monobore whipstock will then be set at 6407' MD inside the 3 -1/2" tubing for a high -side kickoff. Attached to this application are the following documents: — Permit to Drill Application Forms for 31 -11L1, 3I- 11L1 -01, and 31- 11L1 -02 — Detailed Summary of Operations — Proposed Schematic — Directional Plans — BOP Schematic If you have any questions or require additional information please contact me at 907 - 265 -1102. Sincerely, James Ohlinger Coiled Tubing Drilling Engineer RECEIVED (JC T 0 3 2009 Alaska Cif & Gas Cons. Commission Anchorage • TRANSMITTAL LETTER CHECKLIST WELL NAME e(./( l / L PTD# 2 r / .2_/ f/ Development Service Exploratory Stratigraphic Test Non- Conventional Well FIELD: 1� `L POOL: /� -'�t i J r Circle Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK ADD -ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well 1( 3 Ke (If last two digits in Permit No. / 3 WZ% , API No. 50- big - 2-j ?32. 27-a API number are between 60 -69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non - Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev: 1/11/2008 Field & Pool KUPARUK RIVER, KUPARUK RIV OIL - 490100 Well Name: KUPARUK RIV UNIT 31 -11L1 Program DEV Well bore seg ni PTD#: 2091210 Company CONOCOPHILLIPS ALASKA INC Initial Class/Type DEV / PEND Geo Area 890 Unit 11160 On /Off Shore On Annular Disposal ❑ Administration 1 Permit fee attached NA 2 Lease number appropriate Yes Surface location in ADL 025523; top prod interval and TD in ADL 025631. 3 Unique well name and number Yes 4 Well located in a defined pool Yes Kuparuk, Kuparuk Oil Pool governed by CO 432C. 5 Well located proper distance from drilling unit boundary Yes No spacing restrictions with respect to drilling unit boundaries and no interwell 6 Well located proper distance from other wells Yes spacing restrictions. Wellbore will be more than 3 miles from the 7 Sufficient acreage available in drilling unit Yes external boundary of the KRU. 8 If deviated, is wellbore plat included Yes 9 Operator only affected party Yes 10 Operator has appropriate bond in force Yes 11 Permit can be issued without conservation order Yes Appr Date 12 Permit can be issued without administrative approval Yes 13 Can permit be approved before 15 -day wait Yes SFD 10/9/2009 14 Well located within area and strata authorized by Injection Order # (put 10# in comments) (For NA 15 All wells within 1/4 mile area of review identified (For service well only) NA 16 Pre - produced injector: duration of pre production less than 3 months (For service well only) NA 17 Nonconven. gas conforms to AS31.05.030Q.1.A),(j.2.A -D) NA I 18 Conductor string provided NA Conductor set in 31 -11 Engineering 19 Surface casing protects all known USDWs NA Surface casing set in_ 31 -11 20 CMT vol adequate to circulate on conductor & surf csg NA Surface casing cemented in 31 -11 21 CMT vol adequate to tie -in long string to surf csg NA Production casing set in 31 -11 22 CMT will cover all known productive horizons No OH slotted liner laterals 23 Casing designs adequate for C, T, B & permafrost Yes 24 Adequate tankage or reserve pit Yes Rig equipped with steel pits. No reserve pit planned. All waste to approved disposal wells. 25 If a re-drill, has a 10 -403 for abandonment been approved NA Will keep motherbore production. S/T above A sand. 26 Adequate wellbore separation proposed Yes Closest wellbore is 31 -13 at 1500 ft. 27 If diverter required, does it meet regulations NA BOP stack already in place. Appr Date 28 Drilling fluid program schematic & equip list adequate Yes Max fm pressure 4255 psi (13 ppg) ... will use MPD (managed pressure drilling) and 10 ppg mud GLS 10/13/2009 29 BOPEs, do they meet regulation Yes 30 BOPE press rating appropriate; test to (put psig in comments) Yes MASP= 3804 psi Will test BOPs tO 4500 psi 31 Choke manifold complies w /API RP -53 (May 84) Yes 32 Work will occur without operation shutdown Yes 33 Is presence of H2S gas probable Yes H2S on 31 pad. Rig has sensors and alarms. 34 Mechanical condition of wells within AOR verified (For service well only) NA 35 Permit can be issued w/o hydrogen sulfide measures No No, parent wellbore measured 150 ppm H2S during 6/09. Geology 36 Data presented on potential overpressure zones Yes Expected reservoirpressure is 13.0 - 13.7 ppg EMW will be drilled using 10.0 ppg mud and Appr Date 37 Seismic analysis of shallow gas zones NA pressure drilling techniques. SFD 10/9/2009 38 Seabed condition survey (if off - shore) NA 39 Contact name /phone for weekly progress reports [exploratory only] NA Geologic Engineering ublic ►.. Overpressure expected - up to 13.7 ppg EMW. Wellbore will be drilled using 10.0 ppg mud managed and pressure drilling Date: Date Date Commissioner: o ssion C mi er: 0 -r techniques to maintain overbalance. SFD ASP.-
